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Resolution Of 27 October 2010 Of The Ministry Of Energy, Which Approve The Procedures Of Operation System P.o. 3.10, P.o. 14.5, P.o. 3.1, 3.2 P.o., P.o. 9 And P.o. 14.4 For Their Adaptation To The New Rules The...

Original Language Title: Resolución de 27 de octubre de 2010, de la Secretaría de Estado de Energía, por la que se aprueban los procedimientos de operación del sistema P.O. 3.10, P.O. 14.5, P.O. 3.1, P.O. 3.2, P.O. 9 y P.O. 14.4 para su adaptación a la nueva normativa el...

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Article 3.1.k) of Law 54/1997 of 27 November of the Electrical Sector establishes, among the powers that correspond to the General Administration of the State, to approve by means of a resolution of the Secretary of State of Energy the market rules and operating procedures of an instrumental and technical nature necessary for the economic and technical management of the system.

For its part, the Royal Decree 2019/1997 of 26 December, for which the electricity production market is organised and regulated, provides, in Article 31, that the system operator may propose for approval by the Ministry of Industry Tourism and Trade the technical and instrumental operating procedures necessary to carry out the proper technical management of the system, who will resolve prior report of the National Energy Commission.

Royal Decree 134/2010 of 12 February establishing the procedure for the resolution of restrictions for supply guarantees and amending Royal Decree 2019/1997 of 26 December 1997 on the organisation and regulation of the the electricity production market, subsequently amended by Royal Decree 1221/2010 of 1 October 2010 amending Royal Decree 134/2010 of 12 February 2010 laying down the procedure for the resolution of the restrictions on security of supply and amending Royal Decree 2019/1997 of 26 December 1997, for which the the electricity production market is organised and regulated, develops a new system adjustment service known as the 'supply guarantee restriction resolution', which will take place after the appeal of the daily market.

The first paragraph of the third provision of Royal Decree 134/2010, of 12 February 2010, provides that, within a maximum period of three working days following the publication of this royal decree, the system operator must submit to the Ministry of Industry, Tourism and Trade a proposal to revise the operating procedures affected by this royal decree.

View the proposal made by the System Operator of the new operating procedures of the system P.O. 3.10 "Solution of supply guarantee restrictions" and P.O. 14.5 " Salts of the liquidations of the operator of the system for the purposes of Royal Decree 2017/1997 ", and of amendments to the procedures P.O. 3.1" Programming of generation, P.O. 3.2 "Resolution of technical restrictions", P.O. 9 "Information exchanged by the System Operator", P.O. 14.4 "Payment entitlements and payment obligations for the system adjustment services", a made available to the representatives of the subjects of the system in order to receive comments on their content, as provided for in the third provision of Royal Decree 485/2009 of 3 April 2009 regulating the placing on the market the supply of last resort in the electricity sector.

This Secretary of State, prior to the report of the National Energy Commission, resolves:

First. -Approve the procedures for the operation of the electrical system, P.O. 3.10 "Solution of restrictions by guarantee of supply", P.O. 14.5 "Balance of the liquidations of the system operator", P.O. 3.1 " Programming of the generation, P.O. 3.2 "Resolution of technical restrictions", P.O. 9 "Information exchanged by the System Operator", P.O. 14.4 "Payment rights and payment obligations by the system adjustment services", which are inserted into continuation.

Second. This resolution shall take effect on the day following that of its publication in the "Official State Gazette".

Third. From the date on which this resolution takes effect, the following procedures for the operation of the electrical system are without effect:

P. O. 3.1: "Programming of the Generation", adopted by Resolution of the Secretary of State of Energy of 18 May 2009.

P. O. 3.2: "Resolution of technical restrictions", adopted by Resolution of the Secretary of State of Energy of 18 May 2009.

P. O. 9: "Information exchanged by the System Operator", approved by the Resolution of the Secretary of State of Energy of 18 May 2009.

P. O. 14.4: "Payment entitlements and payment obligations for the system adjustment services", approved by Resolution of the General Secretariat of Energy of 28 June 2008.

Madrid, October 27, 2010. -Secretary of State for Energy, Pedro Marin Uribe.

INDEX

P. O. 3.10 Resolution of restrictions for security of supply.

P. O. 14.5 Saldos of the liquidations of the system operator for the purposes of Royal Decree 2019/1997.

P. O. 3.1 Generation programming.

P. O. 3.2 Resolution of technical restrictions.

P. O. 9. Information exchanged by the system operator.

P. O. 14.4 Recovery rights and payment obligations for the system adjustment services.

P. O. 3.10 Resolution of restrictions by security of supply

1. The purpose of this procedure is to establish the process for the solution of the supply guarantee restrictions identified in the daily operating base program (PDBF) that affect the Spanish electricity system.

2. Scope. -This procedure applies to the following subjects:

a) System Operator (OS).

b) Market Subjects (SM).

In the content of this operating procedure, unless expressly stated to the contrary, all references to the subject holders of the programming units shall be understood as also applicable to the representatives of the subject holders of programming units.

3. Supply guarantee restriction. -It is the production that is determined as necessary from those thermal units of electrical energy production that use indigenous primary energy combustion sources to ensure the guarantee of the supply up to the maximum limit laid down in Article 25 of Law 54/1997 of 27 November 1997 and take account of possible limitations of the safety programme which, in accordance with the procedure laid down in the operating procedures, may be required.

For the resolution of these restrictions the mechanisms described in this operating procedure shall apply.

4. Operating plan for the resolution of restrictions by security of supply.

4.1 Determination of the weekly operating plan.-The weekly operating plan for the solution of supply guarantee restrictions will establish, for each day of the week and with a schedule breakdown, the production of plants using indigenous coal as fuel. This weekly plan will cover the time period from 0:00 a.m. each Saturday to 24:00 hours of the following immediate Friday.

By way of exception, the first weekly operating plan will cover the time period from 0:00 a.m. on the first day of the month following the entry into force of this operating procedure and 24:00 hours. of the following immediate Friday.

The programming units corresponding to the power plants listed in Annex II to Royal Decree 134/2010 of 12 February, establishing the procedure for the operation of the system, will be able to form part of this weekly operating plan. (a) a decision on restrictions on security of supply and amending Royal Decree 2019/1997 of 26 December on the organisation and regulation of the market for the production of electrical energy, and which have not achieved the maximum volume of production can be programmed in each central by guarantee of supply fixed annually by Resolution of the Secretary of State for Energy.

The weekly operating plan for each programming unit will be developed by the OS with the objective of reaching the thermal generation volume set annually for each central by Resolution of the State Secretariat of Energy, using indigenous coal as fuel and in a way that can be integrated into the system by ensuring the safety, quality and reliability of the system contained in the operating procedures.

Since the objective of production with autochthonous coal is established in annual terms, prior to the elaboration of the weekly plan, it will be carried out as an analysis base with annual horizon in order to temporarily locate the objective of production in each of these plants in the most efficient way, taking into account the annual seasonality of the demand, the contributions to the hydroelectric reservoirs, the wind and the solar production, as well as the following information communicated to the OS in accordance with the procedure laid down in the operating procedures for which it is established the forecast of the security coverage and analysis of the electrical system, the maintenance plans of the production units and the information exchanged by the system operator:

Previsibilities of generation units inavailabilities.

Central park coal stocks in tonnes (broken down by type) and in millions of PCI and PCS termine.

Level of stock of coal and the maximum storage capacity of coal in the central park.

Structure of consumption and fraction of each type of fuel that needs to be mixed, if any, for environmental reasons.

Expected plan of guaranteed consumption coal deliveries for the remaining months of the current year.

In order to guide the market participants, the results of the analyses that the OS will carry out with an annual horizon, will be published every month in a report in which, with a monthly breakdown, a production plan is reflected with a indicative of plants using autochthonous coal as fuel.

The weekly plan shall be established, in an objective and non-discriminatory manner, taking into account the best forecasts for demand, renewable wind and solar production, cogeneration, hydrolicity, international exchanges, inavailabilities communicated by the generating equipment and the transport network, as well as the weekly information relating to the reservoirs communicated by the companies which own the OS, in accordance with the procedure for establishing the forecasting of the security coverage and analysis of the electrical system and, (i) an indicative working time for each programming unit, which may eventually receive from the MS holders of generation units affected by the supply guarantee restrictions. This indicative schedule may reflect duly justified special operating conditions, such as those associated with the provision of the secondary regulation service by these units.

For the establishment of the weekly operating plan the values corresponding to the minimum and maximum powers of the production units will be respected, according to the information contained in the Register Administrative of Electrical Power Production Facilities (RAIPEE) and that which, if not contained in the RAIPEE, shall provide to the OS the subject holders of the corresponding programming units in a feisty way, and in accordance with the procedure laid down in the procedure for the operation of the exchanges of information with the OS. Further consideration shall be given to the possible transitional limitations of these power values also reported by the subject holders of these units to the OS.

The weekly operating plan established by the OS shall take into account the characteristics of the programming units and the structural information provided by the titular subject in accordance with the operating procedure. establishing the exchange of information with the OS.

4.2 Update of the maximum programmable production volume by security of supply. -The OS will calculate daily, for each of the plants participating in the process of resolution of restrictions by guarantee supply, the maximum volume of production that can be programmed in the process of the resolution of restrictions by guarantee of supply, as the difference between the maximum volume of production fixed for each plant annually by Resolution of the Secretary of State for Energy, in accordance with Annex II to Royal Decree 134/2010, of 12 September The Court of State held that, in the light of the Commission's decision, the Commission had to take into account the fact that, in the light of the information provided by the Commission, the Commission was not required to provide the Commission with a view to the energy actually produced in each of the power plants from the first day of the corresponding year, unless a shorter period of time is established.

This information shall be made available to each of the market subjects holding the plants in accordance with the procedure laid down in the operating procedure establishing the exchange of information with the OS.

4.3 Communication of the weekly operating plan. -On a weekly basis, before 14:00 hours each Thursday and for the horizon covering the whole of the following week (from Saturday to Friday, inclusive), the OS will make available each market subject, in accordance with the procedure laid down in the operating procedure establishing the exchange of information with the OS, the schedule of the schedule of the programming units for the solution of restrictions by security of supply for the following week (from Saturday to Friday, inclusive), which is the holder of each market subject.

By way of exception, the first weekly operating plan will be communicated by the OS to the market participants before 9:00 hours of day D-1, being D on the first day of the month following the month of entry into force of this operation procedure.

4.4 Daily update of the weekly operating plan. -The OS may proceed to make modifications to the weekly operating plan that are necessary to take into account the best information available in relation to the plan. with:

The demand predicted by the OS.

The production forecast for renewable source.

Overcome inavailabilities that affect production units and/or network elements.

On a daily basis, within the time limit set for the communication of prior information to the daily market in the operating procedure establishing the programming of the generation, the OS will make available to each market subject, the updated weekly operating plan for the days following the update referred to in the weekly horizon, corresponding to the programming units for which each market subject is the holder.

4.5 Establishment of the daily operation plan by guarantee of supply. -Within the time limit set for the receipt of nominations after the daily market in the procedure of operation for which the programming of the generation, the OS may receive the nomination, corresponding to the day of programming and with detailed schedule, of the programs of production per unit of programming of the thermal power plants of the updated plan of operation that have two or more programming units associated with them.

In the event that the OS has not received the nomination, or, having received such nomination, the total nominated value is different from the production schedule set for the central in the updated operating plan. corresponding to the programming day, the OS shall assign to each programming unit of the plant the production schedule set out in the updated weekly operating plan.

For all other units included in the updated operating plan, the production schedule for each programming unit will be equal to that set in the updated weekly operating plan.

5. Communication to the Operator of the Operating Programme System.-The subject holders of regular schedule units, not included in Annex II to Royal Decree 134/2010 of 12 February establishing the procedure (a) a decision on restrictions on security of supply and the amendment of Royal Decree 2019/1997 of 26 December on the organisation and regulation of the market for the production of electrical energy, and which they use as part of the fuel for the generation of iron and steel, should make it easier for the OS, the value of the energy sales programme established in the PDBF required for the consumption of steel gas.

These operating programs must be communicated to the OS after the PDBF has been published and within 30 minutes of its publication, so that this information can be taken into account in phase 2 of the process. Resolution of the restrictions by security of supply.

6. Process of resolution of the restrictions by guarantee of supply. -The process for the resolution of the restrictions by guarantee of supply to the daily program base of operation consists of two phases:

Phase 1: Modifying the PDBF program by provisioning security criteria.

Phase 2: Rebalance of generation and demand associated with the solution of supply warranty constraints.

6.1 Phase 1: Modification of the PDBF program for the solution of supply guarantee restrictions. -The objective of this phase is to determine the supply guarantee restrictions that may affect the base program. operation, identifying those program modifications that are necessary to meet the established security of supply criteria, with the respect of the limitations of the program that has been necessary to establish for reasons of system security.

6.1.1 Identification of the restrictions by security of supply. -Restrictions for security of supply shall be identified from the production that is determined in the daily plan of operation by guarantee of supply for the relevant programming day, provided that such production does not result in technical restrictions in the Spanish electricity system, as established in the operating procedures.

6.1.2 Means for the resolution of the supply guarantee restrictions. -To resolve the supply guarantee restrictions identified in the PDBF affecting the Spanish peninsular electrical system, the OS may (a) to establish increases in the programmed energy in the PDBF over the programming units that are part of the daily operation plan by guarantee of supply for the relevant programming day.

6.1.3 Setting limitations for system security. -Before proceeding to the solution of the restrictions for supply guarantee to the daily program base of operation identified in the Spanish electricity system, the OS shall establish, where appropriate, any limitations which are necessary, for reasons of system security, on the production schedules of the units included in the daily operating plan for security of supply and for the day of (a) the corresponding programming, in accordance with the procedure laid down in the operating procedure for which the sets the resolution of technical constraints.

Once the security limitations on the production schedules of the programming units set in the daily operation plan by security of supply are established, the OS will proceed to resolve the restrictions by security of supply to the daily operating base program.

6.1.4 Application of the means of resolution of restrictions for security of supply. -Program increases for the resolution of the supply guarantee restrictions identified in the PDBF shall be carried out by means of the the application of energy redispatches which respect the constraints established by security and, up to the production values set out in the daily operation plan for security of supply, giving rise to new energy programmes which will be established, provided that this is possible, in whole MWh values, and that they will have a value not less than the technical minimum of the corresponding unit, nor greater than the maximum power available in the unit, power which at the limit shall be equal to the net active power recorded for the unit.

In the event that the program increases for the resolution of the supply guarantee restrictions cannot be compensated by the reduction of the programs of the thermal production facilities of the regime Ordinary CO2 broadcasters participating in this process, in accordance with the specific mechanism described in paragraph 6.2 of this operating procedure, the OS may establish programme increments for the resolution of the restrictions by guarantee of supply lower than those set in the daily operating plan by security of supply, as set out in paragraph 6.2.2 of this operating procedure.

The OS will establish the modifications of the programs corresponding to the solution of restrictions by guarantee of supply, indicating for each unit of programming affected by such modification the type and magnitude of the redispatch that is applicable to you in a specific way, for which the following qualification will be used:

UPOPVPGS: Unit with program obligated by security of supply.

Power sales unit for which the coupling or increase of its sales program with respect to the PDBF is required for the resolution of supply warranty restrictions.

Energy redispatches corresponding to the PDBF's resolution of supply guarantee restrictions, once incorporated into the PDVP, will be considered firm, remaining unchanged in the energy programme of the unit.

The programme increases in respect of the PDBF applied for the resolution of the supply guarantee restrictions shall be valued at the price of the energy fixed for each central by the resolution of the Secretary of State for Energy, in accordance with Annex II to Royal Decree 134/2010 of 12 February, establishing the procedure for the resolution of restrictions for security of supply and amending Royal Decree 2019/1997, of 26 December, by which the electricity production market is organized and regulated.

6.2 Phase 2: Rebalance of generation and demand associated with the solution of supply warranty constraints. -Once the supply warranty restrictions identified in the PDBF are resolved and restrictions (a) technical restrictions on the use of the technical restrictions to be used for the modification of the PDBF programme by means of safety criteria, together with the reduction or cancellation of the programmes concerned; bilateral contracts whose generation and/or demand has been reduced in that phase 1, according to the procedure for the operation of the procedure for the resolution of technical restrictions, the OS shall carry out the necessary programme modifications to balance the generation increase which has occurred as a result of the resolution of restrictions by security of supply.

In this process the limitations established, for reasons of system security, will be respected in the first phase of the process of resolution of technical restrictions, according to the procedure of operation by which sets the resolution of technical constraints.

6.2.1 Means to balance the generation increment derived from the resolution of supply warranty constraints. -To balance the generation increase that occurred as a result of the resolution (a) a reduction in the energy programmed in the PDBF by the holders of the energy sales units corresponding to the normal production facilities of the ordinary system of production of the same type of energy. CO2, which use as fuel coal (import or domestic), fuel or natural gas.

The following Common Regime Production Thermal Units of CO2are exempted from participating in this process:

The units participating in the process of resolution of supply security restrictions, in accordance with Annex II of Royal Decree 134/2010 of 12 February, establishing the procedure for the resolution of restrictions on security of supply and the amendment of Royal Decree 2019/1997 of 26 December on the organisation and regulation of the market for the production of electrical energy, and which have not achieved the maximum volume of programmable production for each year by security of supply fixed by the Resolution of the Secretary of State for Energy.

Facilities that perform cogeneration activities.

The installations to which the premium is applied as provided for in Articles 45 and 46 and in the additional provision sixth of Royal Decree 661/2007 of 25 May 2007 regulating the production of electricity on special arrangements.

Production facilities in pre-operational test phase of operation.

Ordinary regime production facilities using as part of fuel for the generation of steel gas, by the values of the operational programme established in the PDBF for the consumption of steel gas, which has been communicated to the OS in accordance with paragraph 5 of this operating procedure.

6.2.2 Application of means to balance the generation increase due to the resolution of supply-guarantee restrictions. -The OS will determine the reductions to be made on the PDBF, to balance in each and each of the programming periods the programme increments which have been produced by the solution of the supply guarantee restrictions taking into account the programme modifications established in the first stage of the process (a) a decision on technical restrictions, once reduced or cancelled, where appropriate, programmes corresponding to bilateral contracts, the generation and/or demand of which has been reduced in that first stage, in compliance with the safety programme limitations applied in the first stage of the technical restriction solution process, in accordance with the procedure for the operation by which the resolution of technical restrictions is established.

In the event that in a schedule period, the schedule increments established for the solution of supply guarantee restrictions are equal to or lower than the time schedule modifications established in the first stage of the process of the resolution of technical restrictions, taking into account where appropriate, the reductions or cancellations of the programmes corresponding to bilateral contracts whose generation and/or demand has been reduced, whose net time balance represents a reduction of the PDBF, the balance shall be deemed to be increase in generation derived from the resolution of supply warranty restrictions.

In the event that the net balance hours of the programme modifications established in the first stage of the process of resolution of technical restrictions, taking into account where appropriate, the reductions or cancellations of the programmes corresponding to bilateral contracts, the generation and/or demand of which has been reduced, results in an increase of the PDBF or the schedule increases established for the solution of supply guarantee restrictions are in excess of the programme modifications established in the first phase of the resolution process of technical restrictions, once reduced or cancelled, where appropriate, programmes corresponding to bilateral contracts whose generation and/or demand has been reduced in that first stage, the net of which represents a reduction of the PDBF, The OS shall determine the units which shall be reduced by its schedule for the solution of the production imbalances resulting from the resolution of supply security restrictions in accordance with the following criteria:

Allocation, first, of the reductions in the PDBF program according to the descending merit order of the CO2 emission levels corresponding to the different coal and fuel programming units programmed in the PDBF and participants in this process, respecting the limitations of the security program established in the first phase of the process of resolution of technical restrictions according to the procedure of operation by which sets the resolution of technical constraints.

When there is more than one unit with the same level of CO2emissions, the program reductions between those units will be distributed by a pro-rata share of the energy to be reduced among all of them with for the unit's PDBF program in the corresponding programming period.

The CO2 emission level for each unit will correspond to the one set in accordance with the fourth paragraph of Annex I to Royal Decree 134/2010 of 12 February establishing the resolution procedure. of restrictions on security of supply and the amendment of the Royal Decree 2019/1997 of 26 December on the organisation and regulation of the market for the production of electrical energy.

Further allocation of the reductions in the PDBF programme for the programming units using natural gas as fuel, in proportion to the energy programmed in the PDBF in the corresponding period of programming.

In the event that after the reduction of each and every program of the PDBF of the units of programming of coal and fuel and, of those that use as fuel natural gas, compatible with the compliance of the limitations For security, it has not been possible to balance the increase of generation derived from the solution of constraints by guarantee of supply, the OS will proceed as follows, once the necessary computer applications are developed and the OS has communicated to market subjects its date of application through the Web of the Subjects of the ESIOS Market:

Reduction, first, of the PDBF program of the participating programming units in the process of resolution of supply security restrictions, according to Annex II of Royal Decree 134/2010, of February 12, laying down the procedure for the resolution of restrictions on security of supply and amending Royal Decree 2019/1997 of 26 December 1997 on the organisation and regulation of the market for the production of electrical energy, reached the maximum programmable production volume for each year by security of supply fixed by the Resolution of the Secretary of State for Energy, up to the energy values set out in the daily operation plan for security of supply.

Reduction of increases in established production schedules for the solution of supply-guarantee restrictions, prorating the energy to be reduced among all units in proportion to the increases in the established production programmes. In this process, the technical minimum of the groups will be respected, taking into account where appropriate, the PDBF program of these units.

If once the increases of the established production schedules for the solution of supply guarantee restrictions to the technical minimum of each of the units were reduced, an imbalance between generation and demand, the increase of production programs will be preferentially annulled by guarantee of supply of those units which, solving the imbalance between generation and demand, will lead to a smaller movement of production increments previously established by supply guarantee in relation to with the weekly operating plan established per unit of programming, in each and every time period of the programming horizon. In this process of reduction, the units which in the PDBF will have a zero schedule program will participate first in each and every one of the periods that constitute the daily programming horizon. In the event that more than one unit has been programmed into the PDBF, the units shall be selected according to the growing order of daily energy programmed in the PDBF and, when the PDBF is matched, they shall be selected following first, alphabetical order and finally, numeric order.

Until the previous IT applications can be available, the OS will cancel, in all time periods of the programming horizon, the production schedules of the programming units. established in accordance with the daily operating plan for the solution of supply guarantee restrictions that are necessary, to the balance of the generation increase resulting from the solution of supply guarantee restrictions. In this process, the limitations established for security reasons of the system will be respected and, whenever possible, the programs of the units that have not been programmed in the PDBF and, preferably those of the those whose cancellation of the program increases for the solution of supply guarantee restrictions leads to a lower energy movement.

In the process of reducing the energy program with respect to the PDBF of the coal, fuel and the natural gas programming units, the energy programs of the units will be respected. have only PDBF program in one or more of the first three time periods that constitute the daily programming horizon, as a load-down ramp associated with a unit decoupling process.

Program reductions for the PDBF that are applied to balance the generation increases resulting from the resolution of the supply guarantee restrictions will be valued at the marginal price resulting from the daily market.

Both the program increases for the solution of supply-guarantee restrictions and the program reductions to balance the increase in generation arising from the previous restrictions will be incorporated into the the provisional viable daily programme (PVP), which shall be published in accordance with the operating procedure establishing the programming of the generation.

7. Inavailabilities of production units included in the weekly operating plan. -Inavailabilities of production units to be communicated after publication by the OS of the updated weekly operating plan be taken into account in the process of the solution of supply security restrictions in the same way as the inavailabilities of production units with influence on the security of the system which have been communicated after publication the PDBF, in accordance with the operating procedure for the establishment of the technical constraints.

8. Information to market subjects. -As a result of the PDBF's process of resolution of supply-guarantee restrictions, the OS will make available to market participants, in accordance with the procedure set out in the operation procedure by the that information exchanges with the OS are established, the following information:

The redispatches to upload applied to the programming units to resolve the supply warranty restrictions identified in the PDBF.

Re-dispatches to download applied to the programming units to balance the generation increments derived from the supply warranty constraint solution.

The OS will also make available to market subjects any update of the information made available to them in the process of resolution of supply security restrictions that have been precise.

These exchanges of information will be carried out through the means and with the structure defined in the current versions of the procedure established for the exchange of information of the OS with the subjects of the market.

9. Solution of anomalies and claims to the process of solution of supply warranty restrictions. -Possible identification of anomalies and/or claims submission to the process of resolution of restrictions by guarantee of supply of the PDBF could lead to the repetition of this process in case the solution of the anomaly so requires, provided that this is possible, with due respect to the maximum allowable time limits established and published by the OS, to ensure that the subsequent programming processes of the programme are not adversely affected. generation.

Once the PDVP or any of the information media associated with the resolution of the PDBF supply warranty restrictions is published, the subject holders of the programming units may submit claims. to this process, within the time limit set in the procedure of operation by which the programming of the generation is established, by means of the Application of Management of Claims made available to these effects by the OS, being able to advance the information regarding the existence of this claim, through communication telephone, fax or e-mail, and in any event the existence of express formal communication through the IT application of claims management, or by a written means (fax or e-mail), is necessary for your consideration as a formal complaint.

10. Participation of the central banks involved in the process of resolution of restrictions for security of supply in the system adjustment services.

10.1 Technical Restrictions Solution Process. -Programming units participating in the process of resolution of supply security restrictions in accordance with Annex II of Royal Decree 134/2010, of 12 The Court of State held that the Court of State held that the Court of State held that the Court of State held that the Court of State held that the Court of State held that the Court of State held that the Court of submit specific tenders for the resolution of technical restrictions in accordance with the procedure of operation by which the technical restriction solution is established.

In the event that in the process of solution of supply warranty restrictions the program of a given programming unit has been increased, any other program increment that is established on that For reasons of system security in the process of resolution of technical restrictions, it will be valued at the price of the simple offer of restrictions, assigning the corresponding block of the offer presented according to the point of operation of the resulting unit after the program increment set for the drive for the solution of supply warranty restrictions.

The bids submitted to the PBF technical restriction solution process by the programming units required to participate in the process of solution of supply guarantee restrictions in accordance with Annex II of Royal Decree 134/2010 of 12 February 2010 laying down the procedure for the resolution of restrictions on supply guarantees and amending Royal Decree 2019/1997 of 26 December 1997 on the organisation and regulation of the market in (i) the production of electricity, will not be taken into account in phase 2 of the process of technical restrictions, where it is necessary to resolve at this stage an excess of generation, in accordance with the procedure of operation whereby the resolution of technical restrictions is established.

The scheduling units enabled for the solution of supply warranty restrictions will participate in the process of solution of technical constraints on the intraday and real-time market, according to the the procedure of operation by which the resolution of technical restrictions is established.

When a programming unit, being required to participate in the process of solution of supply warranty restrictions, has reached the maximum programmable production volume per supply guarantee will pass to participate in the process of solving technical restrictions as set out in the relevant operating procedures.

10.2 Provision of complementary services and participation in the process of management of consumption-consumption deviations. -Programming units participating in the process of resolution of restrictions by guarantee of supply In accordance with Annex II to Royal Decree-134/2010 of 12 February 2010 laying down the procedure for the resolution of restrictions on security of supply and amending Royal Decree 2019/1197 of 26 December 2000, the Commission is organising and regulated the market for the production of electrical energy will participate in the services complementary primary, secondary and tertiary regulation, tension control of the Transport Network and, management of diversion generation-consumption, according to what is established in the corresponding operating procedures.

11. Settlement of the security of supply constraint resolution process. -This section describes in general the main aspects of the process of resolution of supply security restrictions having an impact direct to the settlement of this system tuning service.

The calculation of the receivables and the payment obligations arising from the process of the settlement of supply guarantees is defined in the operating procedure establishing the rights of the collection and payment obligations by the system adjustment services.

11.1 Liquidation of units with PDBF program enabled to participate in the process of solution of supply warranty restrictions. -In the event that a programming unit is programmed into the PDBF and this required to participate in the process of the resolution of restrictions by security of supply in accordance with Annex II to Royal Decree 134/2010 of 12 February 2010 laying down the procedure for the resolution of restrictions by guarantee of supply and change the Royal Decree 2019/1997 of 26 December, for which it is organised and regulated the electricity production market, until it has reached the maximum annual programmable production volume by guarantee of supply, the energy programmed in the PDBF up to, where appropriate, the production value set out in the plan of production. updated daily operation for that unit, shall be valued at the price resulting from the difference between the price of the energy set out in Annex II to the said Royal Decree and the marginal daily market price, where the marginal price is higher than the remuneration price, giving rise to an obligation to pay the subject holder of the unit; and the price resulting from the difference between the price of the energy set out in Annex II to the said Royal Decree and the marginal daily market price, where the marginal price is equal to or higher than the variable cost regulated and below the price of remuneration, established by Resolution in accordance with Annex II to the Royal Decree 134/2010, giving rise to a right of recovery for the subject of the unit.

11.2 Settlement of the provision of the service for the resolution of supply security restrictions. The settlement of the provision of the service for the resolution of supply security restrictions is established in accordance with the redispatched energy and the prices incorporated in these redispatches, applied in the process of resolution of restrictions for the supply of the PDBF, and in cases where applicable, in accordance with the energy measures.

11.3 Liquidation of energy programmes-The redispatches and prices incorporated in the energy programmes applicable to each of the programming units which have modified their programme as a result of the process of The PDBF supply guarantee restrictions are specified in the Annex to this procedure.

11.4 Liquidation in accordance with energy measures. The settlement with measures shall be applicable to the programming units for which an increase in its programme has been established with respect to the PDBF for the resolution of the restrictions by security of supply and for which they have been scheduled in the PDBF, up to the values set out in the updated daily operating plan.

11.5 Distribution of cost overruns resulting from the process of resolution of supply security restrictions. -Overruns of the process of resolution of supply security restrictions will be calculated and passed on. in accordance with the criteria specified in the operating procedure establishing the payment entitlements and the payment obligations for the system adjustment services.

ANNEX I

Redispatches and prices applicable to the provision of the Constraint Resolution Service by the provision of the daily operating base program

1. Scheduled redispatches.

1.1 Increments of the PDBF program for the solution of supply warranty restrictions. -Power redispatches of type UPOPVPGS programmed in the PDVP for resolution of restrictions by guarantee of supply shall incorporate the price of the energy fixed for each plant year by resolution of the Secretary of State for Energy, in accordance with Annex II to Royal Decree 134/2010 of 12 February establishing the procedure for the resolution of restrictions on security of supply and amending the Royal Decree 2019/1997, of 26 December, for which the electricity production market is organised and regulated.

1.2 Reductions in the PDBF program to balance the generation increments derived from the solution of supply warranty constraints. -Power redispatches scheduled in the PDVP to balance the programme increases resulting from the solution of supply security restrictions applied on a daily market transaction (ECOGS redispatch) or on a sales unit associated with a bilateral contract with physical delivery (redispatch ECOCBGS), will incorporate the price corresponding to the marginal market time journal.

2. Effective implementation of the redispatches scheduled in accordance with measures. -The OS shall determine in accordance with the measures, in those cases where applicable, the modifications that are necessary for the prices incorporated in the scheduled redispatches, taking into account the fact that they have been effectively produced in accordance with the measures received, as well as the actual energy measured for the unit and the energy for which it was programmed by security of supply.

In the event that the energy measured in one hour for a programming unit is less than the sum of the programmed energy in the PBF plus the one programmed to go up by security of supply and up to, if any, the value set in the updated operating plan for the solution of supply-guarantee restrictions, the unfulfilled energy shall be valued at the price resulting from the difference between the price of the energy set out in Resolution of Annex II to Royal Decree 134/2010 of 12 February 2010 and the marginal price of the the daily market, giving rise to a payment obligation for the holder where the price of the remuneration is higher than the marginal daily market price and, if not, a charge.

P. O. 14.5 Saldos of the liquidations of the system operator for the purposes of Royal Decree 2017/1997

1. Object. The object of this procedure is:

Set the allocation priority of available funds to balance potential deficits in the monthly settlement of the system operator derived from account annotations whose balance has the income consideration or liquidable costs of the system for the purposes of the provisions of Royal Decree 2017/1997 of 26 December 1997, which organises and regulates the procedure for the settlement of the costs of transport, distribution and marketing at tariff rates, permanent costs of the system and the costs of diversification and security of supply.

Set the average price of payments for capacity to apply to the demand for direct marketers and consumers in settlements without demand measures.

Establish the liquidation of the annual regularization for excess or default in the payment for security of supply as set out in Royal Decree 134/2010 ..

2. Scope. -This procedure of operation applies to the Operator of the System, to the producers with rights of collection for incentive to the investment or for restrictions by guarantee of supply and to the marketers and direct consumers.

3. Average price of payments for capacity in settlements without demand measures. -In the case of non-demand measures the average price of payments for capacity to be applied by the System Operator will be estimated as follows for each subject:

Direct consumers: the price of the payment by capacity to be applied in the unmeasured settlements will be that corresponding to your access rate.

Traders who have one month with the closure of settled demand measures. The average price shall be calculated for each marketer by weighting the prices of each access tariff with the percentage of monthly demand in central bars for each access tariff, obtained with the measures settled in the same month of the year prior to, or in the case of no measures in that month, with the measures of the last month with the settlement of measures.

Marketers who do not have one month with settled demand measures. The price will be calculated for all these marketers, by weighting the prices with the monthly demand percentages in central bars at each access rate obtained with the measures cleared to the demand for free marketalizers, or in their case, of last resort traders, in the same month of the previous year, unless the marketer communicates a justified forecast of percentages of demand.

The percentages reported by the marketer will be applied to obtain their average price of payments by capacity until one month with settled measures.

4. Definitions.

Balance of payments per capacity of settlement n of month m. Difference in the balance of the receivables and payment obligations recorded in the settlements n and n-1 of the month m, as set out in Annex III of Order ITC/2794/2007, of 27 September, for which the electricity tariffs are revised from of 1 October 2007 and the payment entitlements and payment obligations arising from the contracts of the service of availability.

Differential balance of supply guarantee restrictions of month m. Difference in the balance of the receivables and payment obligations recorded in the settlement of the month and n-1 of the month, as set out in Royal Decree 134/2010 of 12 February establishing the procedure for the resolution of restrictions by security of supply.

The differential balance of the power closure of the month m. Difference between the balance of the receivables and the payment obligations entered in the liquidations n and n-1 of the month m, as laid down in the second provision of Royal Decree Royal Decree 485/2009 of 3 April 2009 regulating the (a) the provision of last resort in the electricity sector, and in the fifth additional provision of Order ITC/913/2006, as added in Order ITC/1659/2009 of 22 June establishing the mechanism for the transfer of electricity, market customers at the rate of the supply of the last electric power resource and the calculation and structure of the rates of last resort of electrical energy.

Net differential balance of the settlement of the month m to be settled by the System Operator with the NEC. Sum of the differential balances of payments by capacity, of supply guarantee and power-closing restrictions of the month m that are recorded to the system operator and that have the consideration of income or liquidable cost to effects of Royal Decree 2017/1997.

Funds available in the month M. Funds at the disposal of the system operator to resolve the deficit balances in the closing settlements in the second half of the month M.

5. Settlement with closing in the first half of the month M. -In the first half of month M is closed the Second Provisional Initial Settlement for which the following criteria will apply:

(a) If the differential balances of payments for capacity and supply guarantee restrictions are loss-making, the following shall be done:

The loss-making differential balance of capacity payments shall be apportioned by netting an interim payment obligation to each production programming unit in proportion to its right to charge for investment incentive.

The differential balance loss of supply guarantee restrictions shall be divided by netting an interim payment obligation to each production scheduling unit in proportion to its monthly creditor balance. and payment obligations entered by security of supply.

The system operator will communicate to the National Energy Commission the necessary funds to resolve the outstanding deficit.

(b) If the differential balance of payments for capacity is surplus and the differential balance of supply-guarantee restrictions is loss-making, the first shall be a fund available to defray the second.

If the surplus surplus balance is not sufficient, a provisional payment obligation shall be entered for each production programming unit in proportion to its monthly creditor balance of the payment entitlements and payment obligations. annotated by security of supply.

The system operator will communicate to the National Energy Commission the necessary funds to resolve the outstanding deficit.

If the surplus surplus balance is sufficient and balance is available, it shall be considered as a fund available for settlement in the second half of the month M.

(c) If the differential balance of payments for capacity is loss-making and the differential balance by guarantee of supply is surplus, the second shall be the fund available to defray the first.

If the surplus balance is not sufficient, an interim payment obligation shall be entered for each production programming unit in proportion to its claim for investment incentive.

The system operator will communicate to the National Energy Commission the funds needed to address the previous deficit.

If the surplus surplus balance is sufficient and balance is available, it shall be considered as a fund available for settlement of the system operator with closure in the second half of the month M.

(d) If both differential balances are surplus, the resulting amount shall be considered as a fund available for the settlement of the system operator with closure in the second half of the month M.

6. Settlement with closing in the second half of the month M. -In the second half of month M the following settlements are closed:

First Interim Initial Settlement of the month M.

Interim Interim Settlement of M-3 Month.

Interim Final Settlement of month M-8.

Final Final Settlement of month M-10.

The funds available for closing settlements in the second half of month M will be the sum of:

Funds transferred by the NEC to the system operator to resolve outstanding deficits, received on the business day preceding the day of progress of each settlement.

Excess Balances of Settlements with Closing in the Month M.

Available funds will be allocated with the following priority:

a) The loss-making differential balances of the Final Final Settlement of the month M-10 will be resolved. In the event that the funds were not sufficient:

a.1) The deficits in the balances of capacity and guarantee payments shall be resolved with the priority criteria set out in paragraph 4.

a.2) If the remaining available funds are not sufficient to resolve the outstanding energy shutdown deficit, a provisional payment obligation shall be entered into direct consumers in proportion to their liquidated losses.

As soon as the necessary funds are available to resolve the outstanding deficits, an Exceptional Settlement of Deficits of the Final Final Settlement will be carried out in which only the necessary funds are available. include the annotations relating to regularisation.

b) The loss-making differential balances of the Interim Final Settlement of the month M-8 shall be resolved. In the event that the funds are not sufficient, the same criteria as in point a will apply.

Outstanding deficits will be resolved, if any, in the Final Final Settlement.

(c) The loss-making differential balances of the Interim Interim Settlement of the month M-3 shall be resolved. In the event that the funds are not sufficient, the same criteria as in paragraph 4 shall apply.

Pending deficits will be resolved, if any, in the Provisional Final Settlement.

(d) The loss-making differential balances of the First Provisional First of the month M shall be resolved. In the event that the funds are not sufficient, the same criteria as in paragraph 4 shall apply.

7. Communication of balances to the CNE.-The system operator will communicate to the National Energy Commission the necessary funds to resolve the outstanding deficits of the closed settlements in the month M.

The system operator shall, where appropriate, with the National Energy Commission, liquidate the excess differential balances of the month M settlement, after resolving the deficits of the closed liquidations in the month M.

The system operator will communicate to the National Energy Commission the necessary funds derived from new collection rights decisions affecting outstanding settlements.

8. Regularisations for excess or defect of the remuneration for security of supply.-The system operator will communicate to the Secretary of State of Energy and the National Energy Commission that the plants have exceeded the volume of production of Energy, which is set by the Secretary of State for Energy and which implies a remuneration of more than 5% of the initially established guarantee of supply, for the Secretary of State of Energy to set the new prices of energy. The system operator shall be responsible for the payment of the excess cost of the cost corresponding to the maximum volume of production achieved by the plant.

The system operator shall carry out a final settlement of the excess or default of remuneration on the basis of the calculation of the actual costs communicated to it by the National Energy Commission and on the basis of the aid or other revenue associated with the operation under Royal Decree 134/2010 communicated to you by the National Energy Commission.

For the purposes of the preceding paragraph, the system operator shall communicate to the National Energy Commission the information required.

The excesses or defects of remuneration referred to in Annex II to Royal Decree 134/2010 that are communicated by the National Energy Commission to the system operator after the closing of the Final Settlement One month definitive shall be included in the following settlement of any month.

Payment obligations settled with the system operator for this concept in the month M will not have the consideration of the fund available for the liquidations made in the month M.

P. O. 3.1 "Generation programming"

1. The purpose of this procedure is to establish the process of daily programming of the generation from the nominations of programs derived from the execution of bilateral contracts with physical delivery and the appeal of offers of sale and energy acquisition in the daily and intraday market, so as to ensure the coverage of the demand and the security of the system.

The applicable criteria for the definition of the programming units (PU) used in the programming process of the generation and located in the Spanish electricity system are also incorporated in this procedure.

The programming includes the following successive processes:

a) The daily operating base program (PDBF).

b) The Interim Viable Daily Program (PDVP).

c) The secondary throttling reserve allocation.

d) The final schedules after successive intraday market sessions (PHF).

e) The application, if any, of the deviation management process.

f) The operational schedules set in each hour to the end of the programming horizon (P48).

g) The close program (P48REDRE).

2. Scope. -This procedure applies to the following subjects:

a) System Operator (OS).

b) Market Subjects (SM).

In the content of this operating procedure, unless expressly stated to the contrary, all references to the subject holders of the programming units shall be understood as also applicable to the representatives of the subject holders of programming units.

3. Energy programs, schedules, programming periods, and non-working days. -Energy programs will correspond to MWh values with a maximum of one decimal number.

All schedules and scheduling periods (semi-open temporary intervals defined by their start time and end time) established in this operating procedure are referred to the European Central Time or CET (Central European Time) or CEST (Central European Summer Time).

For the purposes of the programming process established in this operating procedure, it will be business days: Saturdays, Sundays, holidays in the Madrid square, December 24, and December 31.

4. Definitions.

4.1 Daily Operating Base Program (PDBF). -It is the daily energy program, with breakdown by programming periods, of the different programming units corresponding to sales and energy acquisitions in the Spanish peninsular electrical system. This program is established by the OS from the program resulting from the appeal of the daily market communicated by the OM, and the information of execution of bilateral contracts with physical delivery communicated according to the established in the This operation procedure.

4.2 Provisional Viable Daily Programme (PDVP). -It is the daily programme of programming units for energy sales and acquisitions in the Spanish peninsular electricity system, with a breakdown for periods of programming, incorporating the modifications made to the PDBF for the resolution of the restrictions on security of supply and the technical restrictions identified in application of the safety criteria and the modifications required for post-demand rebalancing.

4.3 Secondary Regulatory Reserve Allocation. -Secondary Regulatory Reserve Bid Allocation Process performed by the OS on D-1 day to ensure availability on day D of the regulatory reserve secondary to up and down, required for system security reasons.

4.4 Final Schedule Program (PHF). -It is the programming established by the OS after each of the successive sessions of the intraday market of programming units corresponding to sales and energy acquisitions in the Spanish peninsular electricity system, as a result of the aggregation of all firm transactions formalised for each programming period as a result of the daily viable programme and the appeal of offers on the intraday market once resolved, where appropriate, the technical restrictions identified and carried out rear rebalance.

4.5 Operating hours (P48). -It is the operational programme of programming units corresponding to sales and energy acquisitions in the Spanish peninsular electricity system that the OS establishes in each period of programming to the end of the daily programming horizon. The operating schedule will incorporate all the program assignments and redispatches applied by the OS until publication, 15 minutes before the start of each hour.

4.6 Restriction by security of supply. -It is understood as a restriction by guarantee of supply to the production that is determined as necessary of those thermal units of production of electric power that use sources for the combustion of indigenous primary energy to ensure the security of supply up to the maximum limit laid down in Article 25 of Law 54/1997 of 27 November 1997 and take account of any safety programme limitations which, in accordance with the provisions of the operating procedures, they may be required.

For the resolution of these restrictions the mechanisms described in the operating procedures by which the resolution of the supply guarantee restrictions are established shall apply.

4.7 Technical Restriction. -It is any circumstance or incident arising from the situation of the production-transport system that, due to the safety, quality and reliability of the established supply (a) Regulation (EC) No No 2014

the European Parliament and of the Council of the European Parliament and of the Council of the European Parliament and of the Council

In particular restrictions may be identified due to:

(a) Failure to comply with security conditions under permanent and/or contingency arrangements, as defined in the operating procedure establishing the operational and security criteria for the operation of the electrical system.

b) Insufficient secondary and/or tertiary regulation reserve.

c) Insufficient additional power reserve to ensure coverage of the expected demand.

d) Insufficient capacity reserve for voltage control in the Transport Network.

e) Insufficient capacity reservation for service replenishment.

For the resolution of these restrictions the mechanisms described in the operating procedures by which the resolution of the technical restrictions and the management of the services of adjustment of the system.

4.8 Consumption-consumption.-These are the deviations caused by the differences between actual production and expected generation, variations in the demand for the system and/or the forced modifications of the production programs. As for the existence of significant differences between the expected demand in the Spanish peninsular electricity system and the demand programmed after the results of the different sessions of the intra-day market.

For the resolution of these generation-consumption deviations, the mechanisms described in the operating procedures for the management of the frequency-power regulation services will be applied, and also, when this is applicable, the generation-consumption diversion management mechanism, which is also established in the operating procedures.

the programme is established at the end of the daily programming horizon and contains the programmes resulting from the daily operational programme and the various sessions of the European Parliament. In this context, the Commission will be in a position to take into account the changes in the programmes associated with the process of technical restrictions and the participation of the various units in the system and in the system. Generation-consumption deviation management process.

4.10 Nomination of programs corresponding to the execution of bilateral contracts with physical delivery. -nomination of programs corresponding to the execution of bilateral contracts with physical delivery consists in the communication by the Programming Unit of such bilateral contracts to the System Operator in the form and time limits referred to in this operating procedure.

The nominations of the energy programs corresponding to the execution of bilateral contracts with physical delivery will be made by the seller and the buyer, directly or indirectly, to the Operator of the System:

Direct Nomination: Each of the SM that is part of the bilateral contract with physical delivery nominates to the OS the program of energy of the programming units of which it is the holder (or to which it represents), and with which it wishes execute such bilateral.

Indirect Nomination: One of the SM that is part of the bilateral contract with physical delivery is responsible, prior to the corresponding authorization of the SM acting as a counterpart, to make the nomination of the energy program of each and every programming unit with which both SM plans to implement such a bilateral contract. The SM responsible for making the nomination will be called the Nominator Subject. The authorization of the Nominator, to be effective, must be communicated to the OS. The OS will inform the Nominee Subject of the date from which your authorization to nominate is effective. Once a Nominator has been authorised for a bilateral contract with physical delivery, the latter may only be the subject of indirect nomination. In the case of international bilateral contracts outside the scope of the Iberian Market, the indirect nomination may be made only by the incumbent SM (or the representative) of the UP located on the Spanish side of the corresponding interconnection.

5. Pre-day programming of operation.

5.1 Integration of energy from primary energy emission auctions (SEP), when the exercise of the options is by physical delivery.

5.1.1 Establishment of bilateral contracts for the nomination of the exercise of the options awarded in the auctions of primary energy emissions. -Monthly, at a time of not less than three working days for the first day of each month, the entity with aggregator function in the primary energy emission auctions (EASEP) shall communicate through the indirect nomination system to the OS:

The relationship of the SM holders of primary emission purchase options, arising from the award in such auctions and the possible bilateral transfers of such options, using for this identification the corresponding Energy Identification Code (EIC) codes.

The maximum power value associated with each buyer SM partner-SM seller, and the validity period of this information.

In this case, for the purposes of the indirect nomination of energy programs, the Entity Aggregator of the Primary Emission Auctions (EASEP) is considered to be part of the bilateral contracts with physical delivery (CBEP) in accordance with the arrangements established between this entity and the SM authorised to participate in the Primary Emission Auctions.

Once the above mentioned information of the entity with aggregator function in the primary energy emission auctions (EASEP) has been received, the OS will automatically generate the corresponding information system bilateral contracts with physical delivery associated with the holding of energy purchase options (CBEP), between each of the SM vendors and those SM holders of such energy purchase options, for the execution of the nomination process programs after the exercise of these primary energy purchase options.

The generated CBEPs will have a maximum power value equal to the maximum value communicated by the EASEP to the OS for each buyer-seller pair and will be valid during the period communicated by the EASEP and may be extended, or, to be modified in its maximum power by the successive communications of the EASEP, remaining unchanged the number of performance of the contract.

These CBEPs will use Generic Programming Units (UPG), both for the seller SM and for the buyer SM, units that will have been previously released, for such purposes, in the information system of the System. The discharge of these UPG shall be requested by the OS by the SM in accordance with the provisions established in this respect in the operating procedures, and shall be communicated to the OM through the means and deadlines established.

The OS will validate that the information received from EASEP refers to SM that has the corresponding UPG for the period of validity indicated in the communication. Otherwise, the communication sent by the EASEP will be rejected.

The OS, once released these CBEPs in your information system, will make available to each SM the information corresponding to these bilateral contracts, with respect to the established confidentiality criteria.

In case the EASEP communicates to the OS the early cancellation of a CBEP contract with an SM, the EASEP will no longer send to the OS, as of the date the cancellation is effective, the nomination of the affected CBEP.

In case the OS, as indicated in the operating procedures, suspends the participation in the market of an SM, it will apply what is established in the corresponding operating procedure with respect to the suspension of the SM on the market, in addition, this suspension, to the Market Operator and, where appropriate, to the entities empowered for the nomination of bilateral contracts. During the period of suspension, the daily nomination of bilateral contracts which were in force in force shall be prevented. When the suspension of the SM is complete, this will be again communicated by the OS to the aforementioned entities.

5.1.2 Nomination of bilateral CBEP contracts associated with the exercise of the energy purchase options of the primary emission auctions. -The OS nomination of the bilateral CBEP contracts associated with the exercise of the Energy purchase options after the primary energy auctions shall be carried out by EASEP, under the principle of indirect nomination, before 8:45 h of day D-1, in accordance with the agreements established between EASEP, the SM vendors and the SM buyers of energy purchase options derived from their direct award in the auctions of primary energy emissions, or the subsequent bilateral transfer of such options.

The OS will verify that CBEPs associated with the exercise of primary energy purchase options are nominated for each programming period for a value not exceeding the maximum power of the corresponding CBEP in that period. Otherwise, the nomination of this bilateral contract will be considered invalid and will be rejected. Following this verification, the OS will make available to the SM sellers and buyers the result of the valid nominations of the CBEP, made by the EASEP and corresponding to the exercise of the options for the purchase of energy by the subject holders of those options.

5.2 The explicit daily sub-staff of the exchange capacity in the France-Spain interconnection and Interchanges of information prior to the MD concerning the programming of exchanges in such interconnection. -Two working days before the day of supply, before 16:00 h, the OS will notify the subjects of the authorizations for the programming, relating to the physical rights of annual and monthly capacity.

The differences between the authorisations for the programming and the physical rights of capacity previously allocated will be the possible capacity reductions due to the identification of a congestion situation in the interconnection.

D-1 day, prior to the closing of the MD, and following the schedules fixed in the operating procedure establishing the resolution of congestions in the France-Spain interconnection and in the Joint Rules of Capacity allocation in the France-Spain interconnection, a series of successive processes will be carried out, in the sequence indicated below:

Before 7:45 h of day D-1, the OS will receive from the subjects the notifications of use of the physical rights of annual and monthly capacity that have been authorized.

The lack of notification of the use of authorised capacity by a market subject within the prescribed time limits shall be construed as an automatic resale in the daily auction of physical capacity rights. corresponding.

The operators of the French and Spanish electrical systems will then exchange information regarding the notifications of use received. On the basis of the results of such exchanges of information concerning the use of the authorised annual and monthly physical capacity, the two OS shall jointly establish the total value of physical capacity assigned and the use of which has been reported on both electrical systems.

The communication by the SM of the execution of one or more bilateral contracts between the Energy Sales Programming Unit for import (or the Unit) will be considered to be a notification of the use of physical capacity. Power purchase programming for export) and Generic Programming Units or Physical Programming Units.

Once the notifications of use of the assigned capabilities are exchanged on an annual and monthly basis, the non-notified usage rights will be automatically resold in the corresponding daily auction. In that same process, the two OS will apply the principle of overlapping firm transactions against management, thereby maximizing the use of the exchange capacity.

Before 08:15 h of day D-1, the OS will make available to the OM the information of the physical rights of capacity allocated in annual and monthly horizons and whose use has been reported in both electrical systems.

Once the above process has been carried out, the operators of both electrical systems will jointly publish the information corresponding to the capacity values that will be offered, in one and another sense of flow, in the Daily explicit auction.

Finally, the operators of both electrical systems will proceed to execute the explicit daily auction, then communicating the results of the same, and the corresponding authorizations for the programming, to all and each of the subjects that have resulted in the capacity to be awarded.

After the daily explicit auction, the OS will make available to the OM the exchange capacity value assigned as a result of the daily explicit auction for each subject in each direction of flow, to the object that it is information is taken into account for the acceptance of offers to the daily market.

5.3 Program Transfer of the Generic Programming Units in the PDBF. -The net balance of all transactions associated with the Generic Programming Units of an SM in the PDBF must be null.

In order to cancel the balance of the program transactions of the generic programming units in the PDBF the SM vendors will be able to establish, with respect of the obligations established in the current regulations, the The following types of transactions:

Bilateral contracts with physical delivery between a Generic Programming Unit and one or more Physical Programming Units of the same holder or other subject subject to which a bilateral agreement has been established.

Purchase or power selling transactions established by participating in the daily production market for Generic Offering Units associated with these Generic Programming Units.

Bilateral contracts with physical delivery between Generic Programming Units.

In order to transfer the energy program of the Generic Programming Units through bilateral contracts, the SM will have to be discharged and in effect the bilateral contracts that are necessary, both between two generic programming units, such as between each Generic Programming Unit and the corresponding Physical Programming Units. These bilateral contracts for the transfer of program from the generic programming units to the physical programming units may be national and/or international and must be nominated by the SM according to the rules and deadlines of nomination established in this operating procedure.

5.4 Publication of prior information to the MD. -At a time of not less than one hour from the closing of the period for the submission of offers to the daily market, the OS will make available to all the Market Subjects (SM) and the Market operator (OM), as indicated in the operating procedure setting out the exchange of information with the OS, the information concerning the forecast demand, the network situation planned for the following day, and for those borders in which there is no coordinated mechanism for capacity management provision of exchange capacity on international interconnections (NTC).

At the borders for which there is a coordinated capacity management mechanism, the capacity information made available to the OM and the reporting deadlines for this information will be those indicated in the the procedures for dealing with the resolution of congestion at those borders.

In addition, the system operator will make available to each of the market subjects daily, possible updates of its weekly operating plan, published in accordance with the procedure laid down in the procedure. (a) the operation by which the process for the resolution of supply security restrictions is established, which must be considered as a reason for the development of the forecasts of demand and/or deliveries of production of renewable origin; and/or for over-sold inavailabilities of production facilities and/or elements of the network transport.

5.5 Daily Operating Base Program (PDBF). -The OS establishes the daily operating base program (PDBF) from:

The valid nominations of the programs corresponding to the execution of bilateral contracts with physical delivery made both before and after the daily market, in accordance with the provisions of this procedure operation.

The information received from the Market Operator concerning energy programmes resulting from the appeal of the tenders submitted to the daily production market.

5.5.1 Nominations of bilateral contracts with physical delivery before the daily market.

5.5.1.1 Primary energy emissions contracts, in the event that they are carried out by physical delivery. -Not less than 20:30 hours of day D-2, in case the exercise of the options corresponding to the primary emission auctions shall be carried out by physical delivery of energy:

The EASEP will make the first submission to REE of the information needed for the nomination of CBEP programs for day D.

Before 8:45 hours of day D-1, or exceptionally before 8:55 hours, the OS will receive the nomination for:

Bilateral contracts with physical delivery (CBEP) for the exercise of primary energy purchase options. The nomination of programs of these bilateral CBEP type contracts established between the generic programming units (UPG) of the corresponding sellers and buyers, will be realized, under the principle of indirect nomination, by EASEP.

Before 08:50 hours of day D-1, or exceptionally before 9:00 hours, the OS will make available to the SM:

The information corresponding to the nominations of bilateral contracts with physical delivery of type CBEP, with respect to the criteria of confidentiality established in each case.

In the event of any anomaly in relation to the nomination of CBEPs, market subjects will have a deadline of 9:20 p.m. D-1 to be disclosed to EASEP.

In the event of nomination anomalies, EASEP may submit new nominations for bilateral CBEP-type contracts to the OS. The deadline for receipt in the OS of nominations for bilateral CBEP contracts is 9:30 hours of day D-1.

The OS will make available to market subjects the information corresponding to the nominations of bilateral contracts with CBEP-type physical delivery that have been received from the EASEP once the validation has been carried out. corresponding.

5.5.1.2 International Contracts. -Before 7:45 hours of day D-1:

The OS will receive from the subjects the notifications of use of the physical rights of capacity allocated as a result of the explicit annual and/or monthly auctions in the France-Spain interconnection carried out jointly by the operators of both electrical systems. To this end, the SM shall communicate the execution of bilateral contracts between Physical or Generic Programming Units and the Programming Unit for the purchase or international sale of its authorized entitlement to the SM in the interconnection France-Spain.

Before 9:35 hours of day D-1, the OS will receive the nomination for:

International bilateral contracts outside the scope of the MIBEL with physical delivery in interconnections where there is no coordinated capacity allocation procedure.

International bilateral contracts with physical delivery communicated prior to the daily market in use of the physical rights of capacity allocated in the daily auction in the France-Spain interconnection. The SM may communicate these international bilateral contracts through the use of physical programming units (PUs) or UPG-type Generic Programming Units.

The notifications of use of the physical rights of capacity allocated as a result of the explicit auctions in the Portugal-Spain interconnection carried out jointly by the operators of both electrical systems, once that these auctions have become operational.

These notifications will be made exclusively to the Spanish Electrical System Operator. To this end, the subjects will communicate to the Spanish electrical system operator the execution of bilateral contracts between a Generic Programming Unit located in the Spanish electricity system and a Generic Programming Unit located in the Portuguese electrical system. The Spanish Electrical System Operator will make this information available to the Portuguese Electrical System Operator.

5.5.1.3 Domestic contracts-National bilateral contracts with physical delivery that have chosen the pre-market pre-market nomination option, which may be formalised between two UP, two UPG, or between a combination of both types of Programming Units.

5.5.2 Communication to the OM of the information concerning the bilateral contracts nominated before the daily market. -Before 09:45 hours, the Portuguese OS, on behalf of both OS, will make available to the OM the following information on the nomination of bilateral contracts with physical delivery:

Bilateral contracts with physical delivery in the Portugal-Spain interconnection arising from the use of the physical capacity rights acquired in the explicit coordinated auctions between the two OS, once these auctions have taken place running.

Also, before 09:45 hours, the OS will make available to the OM the information regarding the nomination of bilateral contracts with physical delivery nominated to the OS prior to the daily market.

In the event that you notice that an incident has occurred, the OS, in coordination with the OM, will be able to perform the appropriate actions and, if necessary, new shipments of this information by altering the one already sent. In the event of this situation, the OM and the OS will take their best efforts to ensure that the sequence of operations takes place as soon as possible.

5.5.3 Communication to the OS of the outcome of the appeal by the OM. -Before 11:00 hours of each day, the OS will receive from the OM the information concerning the result of the appeal of offers in the daily market of production corresponding to the supply units of the Spanish electricity system, with the energy programmes contracted on the daily market, including, where appropriate, the energy programmes resulting from the integration into the market of the contracts established on the market with the physical delivery of the energy, the order of merit of the offers of sale and the energy acquisition resulting from the appeal of tenders at that session of the daily market, and all the tenders submitted to that session.

The OS will also receive from the OM the information regarding the marginal price of the daily market corresponding to the Portuguese and Spanish electrical systems for each programming period.

5.5.4 Reception of nominations after the MD. -Before 11:00 hours, or before 30 minutes after the publication of the information corresponding to the results of the hiring in the daily market corresponding to the supply units of the Spanish peninsular electrical system, on those occasions when the system is carried out after 10:30 hours, the OS will receive:

Nominations of programs associated with bilateral contracts:

Bilateral contracts with national physical delivery that have not chosen the pre-market firm nomination option. These bilateral contracts may be concluded between two PUs, two UPG, or any combination thereof. This group will include, among others, bilateral contracts with national physical delivery between marketing companies.

Amendments to national bilateral contracts that have chosen the pre-market pre-market nomination option, provided that this modification involves an increase in the firm energy programme previously communicated and not modify the UP and/or UPG with which the bilateral contract has been previously nominated.

Nominations of the programs contracted in the daily market by offer units (UOs) that have two or more programming units (UP):

A managed energy program on the daily production market for each of the programming units (UP) that make up that offering unit (UO).

Program Nominations associated with supply warranty restrictions:

Nominations of the production schedules per unit of programming of the thermal power plants included in the updated operation plan by solution of supply guarantee restrictions having two or more more programming units.

5.5.5 Communication of UP breakdowns and maximum hydraulic powers per UGH. -Before 11:00 hours of day D-1, or before 30 minutes after the publication of the information corresponding to the the results of the procurement in the daily market:

The holders (or their representatives) shall provide the OS with the information corresponding to the program disaggregations of the programming units per physical unit and, if applicable, by units of equivalent production according to the program breakdown criteria that the OS has set specifically for that programming unit.

The holders of hydraulic management units (UGH) shall provide the OS with the information corresponding to the maximum total hydraulic powers per hydraulic management unit (UGH) which, in case they are For system security reasons, they can be supplied and maintained by each UGH for a maximum of 4 and 12 hours.

5.5.6 Development and publication of the PDBF programme.-The OS will verify the coherence of the nominations of programmes carried out, directly or indirectly, by the market participants and the information concerning the programmes contracted energy in the daily market, received from the OM.

In the event that as a result of the aggregation of the hiring in the daily market and the bilateral procurement, a marketing programming unit, will result with a vendor program, will proceed from the next:

1. The bilateral contracts between the market participants in which the marketing programming unit is involved shall be ordered in order to increase the volume of daily energy.

2. Bilateral contracts shall be withdrawn in the order indicated until the programme of the marketing unit is null or void at all times.

Also, if as a result of this verification any disparity was detected, among the nominations sent by the subject holders of the programming units or between them and the result of the appeal facilitated by The OM shall proceed, depending on the case, as follows:

Programming units with energy program associated with the execution of bilateral contracts: the minimum value of the programs resulting from the communications made by the different identified subjects will be considered as counterparties in that contract.

Programming units with energy program associated with the procurement in the daily production market that are part of other programming units of the same unit of supply: in those cases where the OS does not received the nomination of programs from the integrated programming units in the same offering unit, or having received such nomination, the total nominated value was different from the program of the corresponding offer unit Statement by the OM, will proceed as follows:

1. The programming units shall be ordered in descending order, taking into account their maximum power value.

2. In accordance with the order of paragraph 1 above, the programming units, the programme values up to a value at the limit equal to the hourly energy corresponding to the maximum power of each programming unit shall be allocated to the programming units, assign the program total of the associated offering unit.

3. If once the programmes have been allocated to all the programming units, in accordance with point 2 above, the programme of the unit of supply has not yet been allocated in its entirety, the difference which will be allocated to the programming unit with the largest maximum power value.

Before 12:00 hours of each day, or before 1 hour after the communication to the OS of the information of the results of the procurement in the daily market corresponding to the supply units of the system Spanish peninsular electric, on those occasions when it is performed after 11:00 hours, the OS will make available to all market subjects, and of the OM, the daily operating base program (PDBF) of the programming of the Spanish electricity system for the next day's programming.

From the making available of the daily operating base program (PDBF), the SM will have a maximum period of 30 minutes to make possible claims to the OS due to incidents and anomalies that could be These complaints are dealt with by the procedures laid down for this purpose. In exceptional cases, delays in the publication of the PDBF, or other circumstances as necessary, the OS may reduce the length of the period of receipt of possible claims to the PDBF programme, up to a minimum of 15 minutes, previously reporting this reduction in time via the eSIOS Subject Web.

In cases where the existence of an incident is verified, and it can be corrected without affecting the programming process of the generation, the OS, in coordination with the OM, will carry out the appropriate actions for its resolution and, where appropriate, will proceed with the publication of a new version of the PDBF, keeping the SM of these actions informed at all times, through the website of the eSIOS Subjects. In the event of this situation, the OM and the OS will take their best efforts to ensure that the sequence of operations takes place as soon as possible.

5.6 Information receipt after PBF. -Before 30 minutes after the publication of the PDBF, the SM must communicate to the OS the energy sales program established in the PDBF necessary for the consumption of gas. (a) Steel of those units of ordinary scheme, not included in Annex II to Royal Decree 134/2010 of 12 February 2010, and which they use as part of the fuel for the generation of steel gas.

5.7 Provisional Viable Daily Program (PDVP). -Once the PDBF is published, the OS will consider open the tender receipt period for the technical restriction resolution process. This period of receipt of tenders shall be kept open for 30 minutes.

Taking into account the program limitations that may be required for the safety of the electrical system, the OS will first proceed to make the necessary program modifications to include, the thermal generation with the programming units corresponding to the autochthonous coal plants in accordance with the weekly operating plan for supply guarantee restrictions, in their case up to date.

Next, the OS, taking into account the best forecasts of demand and production of wind origin in the Spanish peninsular electrical system and the expected availability of the network facilities and the production, will apply a security analysis on the daily operating base program (PDBF) to detect possible technical constraints and their possible solutions, selecting those that, resolving the restriction with a margin of adequate security, imply lower cost to the system. The OS will do so to make the modifications of the program that are precise for the resolution of the detected restrictions, and will also establish the limitations of program for safety that are necessary to avoid the appearance of new technical restrictions on subsequent processes and markets, in accordance with the procedure laid down in the operating procedure for establishing the process of resolution of technical restrictions.

In this same process, the OS will introduce the required modifications in the PDBF that have been requested by the distribution network managers in those cases where they identify and communicate in a reliable manner to the OS the existence of technical restrictions on the network which is the subject of its management, in accordance with the procedure laid down in the operating procedure for the resolution of technical restrictions.

Following the resolution of the supply guarantee restrictions and the subsequent resolution of the identified technical restrictions, the OS will proceed to apply a reduction of the programmed values to compensate for that energy. incorporated for the resolution of the restrictions by guarantee of supply which has not already been directly compensated by the modifications of the programme for the solution of technical restrictions the net balance of which represents a reduction of the PDBF respecting the limitations of the programme established for safety reasons, by means of the mechanism established in the procedure for the resolution of supply-guarantee restrictions.

Finally, the OS will proceed, if necessary, to make the necessary additional program modifications to obtain a balanced program in generation and demand for the remaining volume, in accordance with the procedure for the resolution of technical restrictions, while respecting the programme limitations established for safety reasons.

The resulting PDVP program will maintain the existing energy flow between the Spanish and Portuguese systems as a result of the daily market's appeal process.

The program PDVP of the programming units located in the Spanish peninsular electrical system resulting from this process will be published by the OS no later than 14:00 hours, or, before they have elapsed 2 hours from the publication of the PDBF, where the publication of the PDBF is carried out after 12:00 hours, in accordance with the procedure laid down in the procedure for the exchange of information with the OS.

From the making available of the provisional Viable Daily Program (PDVP), the SM will have a maximum period of 30 minutes to make possible claims to the OS due to incidents and anomalies that could be imputable. to the latter, dealing with these complaints in accordance with the procedures laid down for this purpose. In exceptional cases, delays in the publication of the PDVP, or other circumstances as necessary, the OS may reduce the length of the period of receipt of potential claims to the PDVP programme, up to a minimum of 15 minutes, previously reporting this reduction of the deadline via the eSIOS Subject Web.

In cases where the existence of an incident is verified, and it can be corrected without affecting the programming process of the generation, the OS, in coordination with the OM, will carry out the appropriate actions for its resolution and, if necessary, will proceed with the publication of a new version of the PDVP, keeping the SM and the OM of these actions informed at all times, through the website of the eSIOS Subjects. In the event of this situation, the OM and the OS will take their best efforts to ensure that the sequence of operations takes place as soon as possible.

5.8 Intraday explicit auctions of the exchange capacity in the France-Spain interconnection.

5.8.1 First Intraday Auction of Capacity. -Once the PDVP is published, the operators of the French and Spanish electrical systems will exchange, inter alia, the information concerning the exchange programmes international interconnection between France and Spain, which have been nominated by market participants using the physical rights of capacity allocated in the explicit daily auction jointly implemented by the operators of both electrical systems.

After the exchange of information with the operator of the French electrical system the OS will make available to the OM the capacity effectively nominated in the French and Spanish electric systems to the object that it is information is taken into account in the process of accepting bids in the First-to-fifth Sessions, including the intraday market.

On the basis of the results of these programme nominations information exchanges, the two OS will jointly establish the exchange programmes foreseen in the interconnection between France and Spain.

Once these exchange programs are established, the OS will apply the "used or lost" rule to the capabilities assigned on a daily basis and have not been nominated. In that same process, the two OS will apply the overlap of existing firm programs against management, thus maximizing the utilization of the exchange capacity.

Once the above process has been carried out, the operators of both electrical systems will jointly publish the information corresponding to the unused capacity values that will be offered in one and another sense of flow in the first explicit intra-day auction.

Once the explicit intra-day auction is performed, the operators of both electrical systems will proceed to the communication of the results of the same to each and every subject that has been awarded the capacity in the same.

The OS will make available to the SM the total value of the authorizations for programming after such an explicit intra-day auction, indicating the authorized exchange capacity for each subject in each direction of flow.

The OS will make available to the OM the authorizations for the programming established after such an explicit intra-day auction, indicating the total authorized exchange capacity for each subject in each direction of flow, to the the purpose of this information to be taken into account in the process of accepting bids in the first-to-fifth sessions, including the intra-day market.

5.8.2 Second Intraday Auction of Capacity. -Once the PHF for the fifth session of the Spanish production market is published, the operators of the French and Spanish electric systems will exchange, the information relating to the international exchange programmes in the interconnection between France and Spain, which have been nominated within the time limits set by the market participants using the physical rights of capacity allocated in the first explicit intra-day auction held jointly by the operators of both electrical systems.

On the basis of the results of these programme nominations information exchanges, the two OS will jointly establish the exchange programmes foreseen in the interconnection between France and Spain.

Once these exchange programs are established, the OS will apply the "used or lost" rule to the capabilities assigned in the intraday horizon and have not been nominated. In that same process, the two OS will apply the overlap of existing firm programs against management, thus maximizing the utilization of the exchange capacity.

Once the above process has been carried out, the operators of both electrical systems will jointly publish the information corresponding to the unused capacity values that will be offered in one and another sense of flow in the second explicit intra-day auction.

Once this second explicit intraday auction is performed, the operators of both electrical systems will proceed to the communication of the results of the same to each and every one of the subjects that have been awarded capacity in the same.

The OS will make available to the SM the total value of the authorizations for the programming as a result of this second explicit intra-day auction, indicating the authorized exchange capacity for each subject in each flow sense.

The OS will make available to the OM the authorizations for the programming established after this second explicit intra-day auction, indicating the total capacity of the authorized exchange to each subject in each direction of flow, to the the purpose of this information to be taken into account in the tender acceptance process for the first four hours of the first session and the sixth session of the intraday market.

5.9 Secondary Regulatory Reserve Requirements. -Each day, the OS will establish the secondary regulatory reserve requirements for each of the next day's programming periods, as set forth in the the operating procedure for which the reserve for frequency-power regulation is established.

These secondary regulatory reserve requirements required for each programming period of the following day shall be published by the OS before 14:00 hours of day D-1.

5.10 Secondary Regulatory Reserve Allowance. -Once the secondary regulation reserve requirements have been published, the OS will open the process of receiving bids for the provision of the secondary regulation service, the process to be closed at 15:30 hours, except for another indication of the OS which will be communicated in advance to all the MS holders of regulatory zones qualified for the provision of this service.

With the secondary regulation reserve offers received, the OS will allocate the provision of the secondary regulation service with minimum cost criteria, following the process described in the operating procedure whereby the provision of the secondary regulatory service is established.

No later than 16:00 hours of day D-1, the OS will publish, in accordance with the procedures set out in the operating procedure establishing the exchange of information with the OS, the allocation of reserve of regulation secondary for each and every programming period of the next day.

From the making available of the secondary reserve allocation, the SM shall have a maximum period of 30 minutes to make possible claims to the OS for incidents and anomalies that may be attributable to the OS, These complaints are dealt with by the procedures laid down for this purpose. In exceptional cases, delays in the publication of the secondary reserve allocation, or other circumstances as necessary, the OS may reduce the length of the period of receipt of possible claims to the allocation. of secondary reserve, up to a minimum of 15 minutes, and previously reporting this reduction of the deadline via the eSIOS Subject Web.

In those cases where the existence of an imputable anomaly to the OS is verified, and the OS can be corrected without affecting the programming process of the generation in an important way, the OS will perform the appropriate actions. for its resolution and will proceed with the publication of a new version of the secondary reserve allocation, keeping the SM of these actions informed at all times, through the website of the eSIOS Subjects.

5.11 Tertiary Regulatory Reserve Requirements. -Each day, the OS will establish the tertiary regulatory reserve requirements for each of the next day's programming periods, as set out in the operation procedure whereby the reserve is established for frequency-power regulation.

These tertiary regulatory reserve requirements required for each programming period of the following day shall be published before 21:00 hours of day D-1.

5.12 Tertiary Regulation Offers. -Before 23:00 hours of day D-1, the SM will have to present offers of all the reserve of tertiary regulation that have available both to increase and to decrease for the entire horizon of the next day's programming, in accordance with the procedure laid down in the operating procedure laying down the conditions for the provision of the tertiary regulatory service. These offers must be continuously updated by the SM whenever modifications are made in the programming or availability of their production units, the offer of the entire reserve of tertiary regulation being obligatory. available on each drive.

6. Intraday Market (MI). -In the schedule set out in Annex I, the OS shall make available to the OM the information relating to the total capacity of the exchange allocated for each subject in each direction of flow, established after the explicit auction capacity intraday in the France-Spain interconnection applicable to that IM session, in order to ensure that such information is taken into account in the process of acceptance of offers to that IM session.

Programming units affected by bilateral contracts with physical delivery will be able to make program adjustments through the presentation of sales and energy acquisition offerings at the various IM Sessions.

According to the schedules set out in Annex I of this procedure, the OS will receive from the OM the information regarding the result of the appeal of offers in the intra-day market of production corresponding to units of the supply of the Spanish electricity system with the energy programmes contracted on the intraday market, the order of merit of the offers of sale and the purchase of energy resulting from the appeal of tenders in that session of the intraday market; and all tenders submitted to that session.

The OS will also receive from the OM the information regarding the marginal price of each of the intraday market sessions corresponding to the Portuguese and Spanish electrical systems for each programming period.

After the communication by the OM of the program resulting from the appeal of offers, for the units of offer located to the Spanish peninsular electrical system, of each of the sessions of the IM, the OS will receive from the subjects holders, the same information provided by them for the preparation of the PDBF:

Program nominations per programming unit (UP), in cases where two or more programming units are integrated into a single offering unit (UO). The nominated programming unit programmes shall respect, where appropriate, the constraints established by security.

In the event that the offering unit has multiple programming units, either the program nomination of the programming units that compose it is not received, or the program nominations are available these programming units, the total nominated value is different from the associated offer unit program communicated by the OM for the corresponding IM session, will proceed as follows, distinguishing between these two possible cases:

A) The offering unit sells energy in the IM:

1. The programming units shall be ordered in descending order, taking into account their maximum power value.

2. In compliance with the order of paragraph 1 above, the programming units, the programme values up to a value at the limit equal to the hourly energy corresponding to the maximum power or the maximum power limit set shall be allocated to the programming units. their case, by system security for each programming unit and thus allocate the total of the associated offering unit program.

3. If once the programmes have been allocated to all the programming units, as referred to in point 2 above, the programme of the unit of supply has not been allocated in full, the difference which will be allocated to the programming unit with a higher maximum power value.

B) The offer unit buyback energy in the IM:

1. The programming units shall be ordered in descending order on the basis of their programmed energy value.

2. In compliance with the order of point 1, the energy of the programming units shall be reduced to a value equal to zero or equal to that of the minimum power limit set, where applicable, by system security or to the allocation of the total of the the program of the associated offer unit married in the corresponding IM session.

Program breakdowns by physical units or, if applicable, by equivalent production units.

The OS, taking into account all the above information, will perform a security analysis to identify any technical restrictions and, if necessary, resolve them by selecting the withdrawal of this process. The Court of First Instance is of the view that the Court of First Instance does not have the right to provide the Commission with a view to the decision of the Court of Justice of the European Union. additional Spanish necessary for the subsequent rebalancing of the resulting programme that session of the IM.

The PHF program of programming units located in the Spanish peninsular electrical system will be established by the OS from the result of the aggregation of all the firm transactions formalized for each period of programming as a result of the daily viable programme and the appeal of tenders on the intra-day market, after having resolved, where appropriate, the technical restrictions identified and the subsequent rebalancing. The PHF programme will maintain the existing energy flow between the Spanish and Portuguese systems as a result of the intra-day market appeal process.

The OS will publish the final schedule (PHF), with a notice of no less than 15 minutes before the start of the horizon for the implementation of the corresponding IM session, in accordance with the procedure of the the operation by which information exchanges with the OS are established.

In cases where the existence of an incident is verified, and it can be corrected without affecting the programming process of the generation, the OS, in coordination with the OM, will carry out the appropriate actions for its resolution and, where appropriate, will proceed with the publication of a new version of the PHF, keeping the SM of these actions informed at all times, through the website of the eSIOS Subjects. In the event of such a situation, the OM and the OS shall take the necessary steps to ensure that the sequence of operations is carried out as soon as possible.

In cases where, for some delay or other operating condition, the publication of the corresponding PHF is not possible before the beginning of the horizon of application of an IM session, the OS will suspend the application of the PHF at that time, communicating this fact to the SM, to the OM, to the appropriate effects.

7. Exchanges of information after the intra-day market for the programming of international exchanges. It is time to establish the final values of the exchange programs per subject that will be taken into consideration for the Setting the adjustment value of the frequency-power regulation system in charge of controlling the exchange of energy between the two electrical systems that share each electrical interconnection, only those systems will be considered. energy programmes which have been properly nominated, and with respect to the deadlines set.

After each session of the IM, the OS will exchange with the operators of the neighboring electrical systems the information of the nominations of energy programs of the SM, in order to establish jointly the the end values of the exchange programs in the corresponding pipeline.

This same exchange of information will also be carried out in cases where a congestion situation has been identified in an international interconnection during the operation in real time, to proceed with the resolution of such congestion through the implementation of a reduction of the planned exchange programmes.

8. Management of deviations. -The deviations between generation and consumption over the inavailabilities of the generating equipment and/or modifications in the forecast of the demand and/or in the forecast of the production of special regime not manageable and/or significant differences between the expected demand and the envisaged demand in the market resulting from the market may be resolved by the application of the diversion management mechanism, provided that the conditions for the application of the system are met. mechanism set in the operation procedure that the solution process is established of the generation-consumption deviations.

The solution of these deviations will cover up to the start time of the application horizon for the next IM session.

9. Real-time programming.

9.1 Operational schedules (P48). -P48 are the schedules that result after the incorporation of all the assignments made in firm up to the time of the publication of these programs of the units programming located in the Spanish peninsular electrical system.

Each of the P48 shall be published in accordance with the procedure laid down in the operating procedure establishing the exchange of information with the OS, at a time of not less than 15 minutes in advance of the change of time.

9.2 Immediate actuations to imbalances in real time. -At the time when there is an imbalance between generation and consumption, the immediate action of the primary and secondary regulation to correct the imbalance, with consequent loss of regulatory reserve.

If the secondary regulation reserve is reduced below desirable levels for system security reasons, the OS will require the use of tertiary regulation reserve to regenerate the secondary reserve, by applying the procedure for the operation whereby the provision of the tertiary regulatory service is established.

9.3 Modifications of the P48. -modification of a P48 with respect to the previous one may be motivated by:

(a) Amendments to the energy sales and procurement programmes carried out in the IM Sessions, or by the application of the diversion management procedure, or by the allocation of tertiary regulation offers.

b) Over-come inavailabilities of the physical units of production in the period between the communication of two consecutive P48.

c) Forecasts of the evolution of demand and/or production of wind origin until the next session of the IM, carried out by the OS, and which differ from the total demand and/or the programmed wind production resulting from the previous IM session.

d) A solution for real-time restrictions alert situations.

e) Fehaciente communication of the subject of a production unit, or of a unit of pumping consumption, of the existence of deviations on the program due to the technical impossibility of fulfilling the program, certain discharges, etc.

f) The operator of a neighbouring electricity system operator of the total or partial non-compliance of the energy exchange programme which is intended to be carried out by a market subject.

9.4 Resolution of restrictions detected in real time. The modification of the programming for the resolution of the restrictions identified in real time will be carried out according to the procedure of operation sets the technical constraint resolution process.

10. Closure programme (P48RENER).-After the end of the daily programming horizon, the OS will make available to the subject holders of the programming units the closing programme (P48RENER) corresponding to the final production programmes and consumption resulting from the different markets and from the participation in the system adjustment services.

11. Information to the OM and the market subjects. -All exchanges of information between the OS and the OM and the SM carried out in the framework of the process of programming of the generation, will be carried out using the means and the structure previewed in the Existing editions of the procedure established for the exchange of information of the OS with the market subjects and the joint procedure agreed between the OS and the OM, in accordance with the procedure of the procedure for which the establish information exchanges with the OS.

12. Programming units in the Spanish penisar electrical system. -The process of daily programming of the generation is based on the management of the energy programs of the different programming units corresponding to the sale and the energy acquisition in the Spanish peninsular electricity system. Some terms associated with the management of the programming units are defined and described in detail below.

12.1 Programming Unit Definition-The Programming Unit is the elementary unit of representation of the energy programs defined in this Operation Procedure.

The Programming Units allow the integration into the Spanish peninsular market of the programs of sale or acquisition of energy corresponding to an individual installation, to which it will be called Physical Unit (UF), or a set of them according to the criteria set out in Annex II to this procedure. They also allow the integration into the market of the import and export programs of energy made through international interconnections.

In Annex II of this procedure, the Generic Programming Unit (UPG) is defined for:

The integration into the energy production market from the primary energy emission auctions (SEP), in case the exercise of options is performed by physical delivery.

The notification of capacity usage in the pipeline with France.

The integration into the production market of engaged generation in physical bilateral contracts.

The Programming Unit (UP) and, where appropriate, the Generic Programming Unit (UPG) is also the elementary unit for the recording of the payment entitlements and the payment obligations that correspond to it in the Register of System Operator Account Log.

The identification codes for these units will be provided by the System Operator once accepted as the Programming Unit and/or the Spanish Electrical System's Generic Programming Unit.

A single Programming Unit and/or Generic Programming Unit may have associated energy programmes corresponding to the different forms of procurement (managed transaction in the organised market and one or more transactions affecting bilateral contracts with physical delivery).

In the case of shared ownership units, the Programming Unit will be unique, and the co-owner who acts at each moment as the controller of the control center of the same will be able to vary in time.

12.2 Holder of the Programming Unit. -The holder of the Programming Unit (and/or the Generic Programming Unit) will be the Subject of the market responsible for this Programming Unit (and/or Generic Programming Unit) in the Spanish production market.

In the case of Programming Units corresponding to production facilities or to direct consumers on the market, the operator of the Programming Unit shall be the owner of the installation, understanding as such subject to the holding of the operating rights of the facility, or the co-owner who exercises at each time as the controller of the control centre of the facility.

In the case of the aggregator Programming Units, which are defined in Annex II, corresponding to the Subject of Representatives, Traders of Last Resource or Traders, the holder of the same shall be the Subject Representative, Last Resource Marketer, or Marketer.

In the case of Programming Units used to integrate into the market the transactions of import or export of energy made through international interconnections, the holder of the Programming Unit shall be the subject of the market which has been authorised for such international exchanges.

In the case of Programming Units used for the integration into the market of energy production from the auctions of primary energy emissions (SEP), the holders of the General Programming Units will be, respectively, the SM seller and the SM holder of power purchase options.

In the case of Generic Programming Units used for the communication of international transactions firm in the interconnection with France the holder of the Programming Unit will be the Subject of the market that has been approved for the implementation of such international exchanges.

It will be up to the Subject Subject:

a) The request for high, low, and communication of modifications relative to the programming unit in the OS information system.

b) Where appropriate, the communication to the OS of the designation of a Representative Subject (RST) for the day-to-day management of that Programming Unit.

c) Communicate to the OS the schedules of energy of that Programming Unit, communicating, in addition, in their case, the Programming Units acting as counterparties in the case of transactions corresponding to contracts bilateral with physical delivery.

(d) to provide to the OS the programmes disaggregated by physical units and/or, where appropriate, equivalent production units, in accordance with the criteria for unbundling of programmes which have been set up by the OS in a specific manner; The Programming Unit.

e) Interlocution for the exchange of information with the OS.

12.3 Representative of the Programming Unit.-The Representative of a Programming Unit shall be a subject designated by the titular subject of the Programming Unit to act on behalf of the holder, either in his own name or on behalf of others, on the Spanish Production Market using the same Programming Units as the holder of the holder except in the cases set out in Annex II.

The designation of the Representative of the Programming Unit shall be made by the holder's presentation to the OS of the corresponding power of attorney that accredits this fact.

The Representative of the Programming Unit shall be responsible for the execution of the functions listed in the preceding paragraph in points (a), except for the communication of ups and downs to be performed by the subject (b) the holder of the programming unit, (b) in the case where the representative is no longer representing the holder and (c) to (e), both inclusive.

In those cases where a trader integrates in the market national production of ordinary regime, the trader shall act for all purposes as a representative of the holder of the said Units of Programming.

13. Testing of new information systems. -Before any new exchange of information is put into operation, the system operator will propose a prior stage of carrying out the relevant information exchange tests between all affected subjects.

ANNEX I

Schedules set for information exchanges

1. Schedules for publication of programs and other information exchanges.

Concept

Time

Notification to SM authorisations for programming relating to the physical rights of capacity allocated in explicit auctions in the France-Spain interconnection and, where applicable, in the Portugal-Spain interconnection (D-2 or previous day).

D-2
< 16:00 hours

Nomination to the OS of the allocated capacity at the explicit annual and monthly capacity auctions in the France-Spain pipeline.

< 7:45 hours

The OS makes available to the OM and the SM the information of the physical rights of capacity obtained in annual and monthly horizons for the France-Spain interconnection whose use has been notified in both electrical systems.

< 08:15 hours

In your case, EASEP makes an indirect nomination of the CBEP with formalized physical delivery between UPG of the SM seller and buyer.

< 8:45 hours

Where appropriate, the OS makes available to the SM the information corresponding to the nominations of bilateral contracts with physical delivery of type CBEP.

< 08:50 hours

Publication by the OS of the information prior to the MD.

< 09:00 hours

Communication by SM to OS of bilateral contract nominations:

< 9:35 hours

bilateral contracts with physical delivery through interconnections outside the scope of the MIBEL in which a coordinated capacity allocation procedure.

applicable, the notifications of use of the physical rights of capacity allocated in the explicit auctions in the Portugal-Spain interconnection carried out jointly by the operators of both electrical systems.

Contracts National bilateral with physical delivery who have chosen the pre-market firm nomination option

appropriate, the Portuguese OS on behalf of both OS will make available to the OM:

< 9:45 hours

regarding the nomination of bilateral contracts with physical delivery in the pipeline Portugal-Spain arising from the use of the physical rights of capacity acquired in explicit auctions.

The maximum usable capacity values in the bidding process in the Daily and Intradiary (ATC) Market

Puesta a Provision of the OM of information concerning bilateral contracts nominated to the OS prior to the MD, and of the capacity allocated in daily auction on interconnections with coordinated capacity allocation procedure

< 09:45 hours

PDBC Publish.

< 11:00 hours

by SM to OS of program nominations per unit of programming:

< 11:00 hours (in any case, up to 30 min after PDBC publication)

Contract Nominations after the MD.

Programming Units program nominations, integrated with other UP in a single offering unit

Nominations of the production programs by UP of the thermal power stations included in the updated operation plan solution of supply warranty constraints that have two or more of the UP.

the SM to the OS of the program for:

UF Unaggregations

UGH maximum hydraulics

PDBF Publication.

< 12:00 hours

Presentation of offers for technical constraint resolution processing.

12:30 hours (in any case, up to 30 min after PDBF publication)

Puesta a Provision of the SM and the OM of the results of the auction of capacity for bilateral contracts with physical delivery performed, in case of congestion, on interconnections, outside the scope of the MIBEL, without coordinated capacity allocation procedure

< 14:00 hours

< 14:00 hours

throttling requirements.

< 14:00 hours

Presentation of secondary throttling.

< 15:30 hours

regulation reserve allocation.

< 16:00 hours

Tertiary regulation reserve requirements.

< 21:00 hours

Tertiary Regulation Offering Presentation.

< 23:00 hours

Notes:

D: Programming Day. Except for another indication, all previous schedules correspond to day D-1 (day immediately prior to the operation).

In cases where the existence of an incident is verified, and it can be corrected without affecting the programming process of the generation, the OS, in coordination with the OM, through the corresponding specific messages and deadlines for submission, shall carry out appropriate action for its resolution and, where appropriate, shall publish new versions of these publications (Communication from bilateral, PDBF, PDVP and PHF), keeping informed at all times to the SM of these actions, through the Web of the eSIOS Subjects. In the event of this situation, the OM and the OS will take their best efforts to ensure that the sequence of operations takes place as soon as possible.

In case of delays in any other publication, schedules are modified as described in the text of the Operation Procedure. If, as a result of these delays, the sequence of programming of the operation is affected, the OS will inform the SM in a timely manner using the Web page of the Market Subjects, the eSIOS.

2. Release schedules for PHFs after intraday market sessions.

Logout.

Session 1.

Session 2.

Session 3.

Session 4.

Session 5.

Session 6.

Session Opening.

16:00

21:00

1:00

4:00

8:00

12:00

17:45

21:45

1:45

4:45

8:45

12:45

Cassation.

18:30

22:30

2:30

5:30

9:30

13:30

nominations by UP and program disaggregations.

19:00

23:00

3:00

6:00

10:00

14:00

Analysis.
Recuse after constraints.

19:10

23:10

3:10

6:10

10:10

14:10

PHF Publication.

19:20

23:20

3:20

6:20

10:20

14:20

Programming Horizon.

28 hours

24 hours

20 hours

17 hours

13 hours

9 hours

(Time periods).

(21-24)

(1-24)

(5-24)

(8-24)

(12-24)

(16-24)

3. Schedules of the coordinated system of explicit daily and intra-day capacity auctions in the France-Spain interconnection.

Auction
daily (D-1)

1. # Subasta
intra-day (D-1)

2. # Subasta
intraday (D)

Preacquired capacity OS nomination limit

7:45

15:00

10:25

of Nominations between OS

7:55-8:05

15:35-15:40

10:35-10:40

Publication of the auction specification

8:35

16:05

11:05

Receive Period Receive

8:45

16:15

11:15

receipt period offers

9:15

16:45

11:45

9:30

17:00

12:00

9:30

17:00

Communication to SM and OM of assigned capabilities

9:30

17:15

12:15

ANNEX II

Programming units located in the Spanish peninsular electrical system

1. Programming units for the acquisition of energy. -They are the corresponding to commercializers of last resort, direct consumers in market, consumption of pumping, marketers, representatives in own name, consumption of producers and exporting power to external systems.

a) Programming unit for the acquisition of energy by marketers of last resort. -Each Subject Merchant of last resort with supply at tariff or last resort shall be the holder of a single Unit of Programming for the provisioning of your clients for last resort provisioning.

b) Programming unit for direct energy acquisition by direct consumers on the market. -Each Direct Consumer in Market will be the holder of a single Programming Unit for all its supplies within the Spanish peninsular electrical system of which it is a Liquidation Subject.

c) Programming Unit for the acquisition of energy for pumping consumption. -Each Producer Subject owner of a pumping facility shall be the holder of a single Programming Unit for the acquisition of energy for pumping consumption of the set of groups coupled in the same knot of the Transport or Distribution Network.

This Programming Unit for pumping consumption of that set of groups, will be different from the Programming Unit that will be assigned to the same installation for the production programming corresponding to the process of turbination of that same set of pumping groups.

d) Programming Unit for the acquisition of energy for supply to domestic consumers by marketers or representatives on their own behalf and on behalf of others. -Each Representative Subject in his own name and on behalf of An employee or a marketer shall be the holder of a single Programming Unit for the supply to all its direct consumer customers within the Spanish peninsular electricity system.

In the event that a direct consumer on a market with a representation on behalf and on behalf of the market operator chooses to be represented, the corresponding representative may use the programming units with which the direct consumer would act on the market.

e) Programming Unit for the acquisition of energy by producers (auxiliary consumption). -Each Producer may be the holder of a Programming Unit for the acquisition of energy for the supply of all those ancillary services of its facilities that are not fed from its own production units, with ancillary services being understood as the electrical energy supplies needed to provide the basic service in any of the operation of the plant (load, start, stop and emergency), including supplies to electrical equipment and drives associated with the various processes of the plant, control facilities, telecommunications, mechanical installations and power and lighting.

f) Programming Unit for the acquisition of energy for export from the Iberian electrical system to external systems. -Each authorized subject for the export of energy from the Iberian electrical system to systems (a) shall be the holder of a Programming Unit for the integration into the market of the energy export programme through each of the international interconnections for which it has the relevant authorisation, or authorized a transit of energy representing an export operation through such interconnection.

g) Programming unit for the acquisition of energy on the market with the intention of exporting to the French electricity system without having capacity rights. -Each Subject authorised for the export of energy to France shall also be the holder of a Programming Unit for the acquisition of energy on the market, without the provision of capacity rights and with the intention of its export to the French electricity system.

2. Programming units for the sale of energy

These are those for domestic production facilities, belonging to the ordinary regime and special arrangements, imports and sales in the daily market for the excess of the term purchases of the latter resource.

(a) Programming unit for the sale of energy corresponding to the production of ordinary power plants. ' A Programming Unit shall be set up for each thermal power plant, under the terms of the thermal power plant an electrical power production facility that can operate separately from the other production facilities with which it can share the same connection knot to the Transport Network or the Distribution Network.

A Thermal Programming Unit shall normally be composed of a single physical unit, except in the case of multi-axle power plants, such as certain combined cycle groups (X plus gas turbines and steam turbines), which integrate as many physical units as the number of turbines make up them.

The holder of these Programming Units shall be the same producer as the owner of the plant, or the co-owner who acts at each time as the controller of the control centre of the plant, in the case of central shared ownership.

In case the owner of an ordinary regime production facility decides to establish a marketing contract with a Marketing Subject to integrate its production into the market, this marketer act with the same programming units as the Owner Subject would do.

b) Programming unit for the sale of energy corresponding to the production of hydraulic management units of ordinary regime. -A Programming Unit to be called Hydraulic Management Unit (UGH) will be constituted. for each set of hydroelectric power plants belonging to the same hydraulic basin and to the same holder.

The holder of this Programming Unit shall be the Producer Subject itself which owns this set of plants, or the co-owner who acts at each time as the controller of the control centre of the assembly. in the case of shared ownership power stations.

In case the owner of an ordinary regime production facility decides to establish a marketing contract with a Marketing Subject to integrate its production into the market, this marketer act with the same programming units as the Owner Subject would do.

c) Programming unit for the sale of production of reversible central pumping stations. -A Programming Unit shall be set up for each set of groups associated with a reversible pumping station which to evacuate in a certain node of the Transport or Distribution Network and is owned by the same Producer or set of producer subjects.

This Power Selling Programming Unit will be different from the Programming Unit that will be assigned to the same installation for the programming of the pumping consumption of that same set of groups.

The holder of this Programming Unit shall be the Producer Subject itself which owns this set of plants, or the co-owner who acts at each time as the controller of the control centre of the assembly. in the case of shared ownership power stations.

In case the owner of an ordinary regime production facility decides to establish a marketing contract with a Marketing Subject to integrate its production into the market, the marketer act with the same programming units with which the Owner Subject would do so that their performance will be similar to that of a Representative Subject.

(d) the unit for the production of special arrangements for the production of special arrangements on the market in the production market through the producer subject;-a production planning unit for the production of special market regime for each Producer and type subject to the operational classification established by the System Operator and published on the website of the eSIOS market participants. In this way, each Producer subject will be the holder of many special regime programming units as production types compose their generation park so that each Programming Unit integrates into the market the production of a single type.

In addition, for each type of programming unit of a special type of management, there will be two Programming Units, one that will group the facilities eligible for participation in the System adjustment services of a potestative nature, and another grouping facilities that are not eligible for the provision of these potestative services.

In the event that the specific features of any installation make your treatment individualized by the System Operator, the Producer Subject will have the corresponding Programming Unit.

(e) Programming Unit for the sale of special regime production in the market economy of the market integrated in the production market through the Subject Marketer or Representative in its own name. o Representative acting in his own name and on behalf of others shall be the holder of so many special regime programming units on a market economy as rates, in accordance with the operational classification established by the OS, make up the park of generation with which he has established a marketing contract or a representation on behalf of others, so that each of its aggregating Programming Units integrates into the market the production corresponding to a single type.

For each type of special regime production aggregator programming unit manageable, two Programming Units will exist; one that will group the facilities enabled for the participation in the setting up of the potestative system, and another grouping of facilities not eligible for the provision of these services.

In the event that the specific features of any installation make it necessary to be treated individually by the System Operator, the Producer Subject will have the corresponding Programming Unit, which will be integrated into the system by its Representative or Marketer Subject.

Each Marketing Subject or Representative in his own name and on behalf of others may also act with the same programming units with which the Producer Subject would participate in the production market.

f) A special regime production sales aggregator unit under the economic regime of an integrated tariff on the production market through the Producer Subject, Representative on its own behalf or Marketer. -Each Subject Owner or Representative acting in his own name and on behalf of an employee or a trader shall be the holder of, at most, two units of Programming for the sale of special regime production on an economic tariff rate for each of the types, of programming units established and published by the System Operator in the the website of the eSIOS market, which consists of the special regime generation park at the rate it integrates on the market. The first of these will integrate the production of all facilities of the same type that are not exempt from the payment of the cost of diversion and the second will integrate the production of those facilities of the same type that are exempt from the payment of the cost of deviations. In this way, each of its aggregating Programming Units will integrate in the market the production corresponding to the production of the same type and of the same way of liquidation of the deviations.

In the event that the specific features of any installation make it necessary to be treated individually by the System Operator, the Producer Subject will have the corresponding Programming Unit, which will be integrated into the system by the same or its Representative or Marketer Subject.

Each Marketing Subject or Representative in his own name and on behalf of others may also act with the same programming units with which the Producer Subject would participate in the production market.

g) Energy sales programming unit for the import from external systems to the Iberian electrical system. -Each authorized subject for the import of energy from external systems to the Iberian electrical system will be the holder of a Programming Unit for the integration into the market of imported energy through each of the international interconnections for which it has the relevant authorisation for the import of energy; or has authorized a power transit that represents an import operation through such interconnection.

(h) The planning unit for the sale of energy on the market with the intention of importing it from the French electricity system without having capacity rights. -Each authorised subject for the import of energy from France shall also be the holder of a Programming Unit for the sale of energy on the market, without the provision of capacity rights and with the intention of importing it from the French electricity system.

3. Generic programming units.

a) Generic Programming Units (UPG) -Generic programming units used for:

The integration into the energy production market from the primary energy emission auctions (SEP), in case the exercise of options is performed by physical delivery.

The notification of capacity usage in the pipeline with France.

The integration into the production market of engaged generation in physical bilateral contracts.

ANNEX III

Programming units located in the Portuguese continental electrical system

The programming units located in the Portuguese electrical system shall be established on the basis of the criteria established by the Portuguese electrical system operator.

ANNEX IV

Statement of high bilateral contracts with physical delivery to the system operator

Bilateral contracts with physical delivery may be established among market subjects (producers, marketers, direct consumers on the market and marketing of last resort) using the physical or generic programming as set out in Annex II.

The declaration of bilateral contracts will be made from the SM Web page.

After the high bilateral contract request, the OS will review if the information about the contract is correct and complete and will proceed to communicate the date of discharge to the requesting SM.

International bilateral contracts for the import of energy in the scope of the MIBEL shall be associated only as a selling unit for the corresponding programming unit for the import of energy.

International bilateral energy export contracts in the scope of the MIBEL shall be associated only as a purchasing unit for the corresponding programming unit for the export of energy.

The nomination of these declared contracts to the System Operator shall be in accordance with this procedure and shall respect the schedules of communication to the OS set forth therein.

P. O. 3.2 Resolution of technical restrictions

1. The purpose of this procedure is to establish the process for the resolution of the technical restrictions identified in the Spanish peninsular electrical system in the daily program base of operation (PDBF) and in the resulting programs of the different sessions of the intraday market, as well as those that can be identified later during the operation in real time.

2. Scope. -This procedure applies to the following subjects:

a) System Operator (OS).

b) Market Subjects (SM).

In the content of this operating procedure, unless expressly stated to the contrary, all references to the subject holders of the programming units shall be understood as also applicable to the representatives of the subject holders of programming units.

3. Resolution of technical restrictions on the daily market.

3.1 Reception of the program resulting from the appeal of the daily market and the nominations of the program. -Before 11:00 hours of each day, the OS will receive from the OM the information regarding the result of the appeal of offers in the daily production market, with the energy programmes contracted in the daily market, including energy programmes resulting from the integration into the market of the contracts established in the market in the forward market under the option of physical clearance of energy.

Before 11:00 hours of each day, or before 30 minutes after the publication of the information corresponding to the results of the procurement in the daily market, when it is carried out after At 10:30 a.m., the OS will receive from the subject holders, for the process of analysis and resolution of technical restrictions, the nominations of the schedules of energy corresponding to the execution of bilateral contracts with delivery (a) physical, in accordance with the procedure laid down in the procedure for establishing the programming of the generation.

3.2 Disaggregation of the programs of the sales and energy acquisition programming units and the communication to the OS of other information necessary for the security analysis. -Before 11:00 hours of each day, or within 30 minutes of the publication of the result of the appeal of the daily market, when this publication takes place after 10:30 hours, the subject holders of the programming units shall provide the next information:

Information for unbundling in physical units of the power program for each programming unit:

The subject holders of each and every programming unit integrated by more than one physical unit shall provide the OS with the information concerning the disaggregations of the energy programmes allocated to each of them. of the physical units that make up each programming unit, so that this information can be taken into account in the system security analysis.

This breakdown of programs will be applicable, in the case of power sales programming units, to all units composed of more than one physical unit and corresponding to:

Sales units corresponding to a thermal power plant (UVT) composed of several physical units (multi-axis thermal units).

Hydraulic Management Units (UGH).

Energy sales units for reversible pumping stations (UVBG).

Energy sales units corresponding to the production of a manageable special regime (UVREG) from non-renewable sources (UVREGNR) and renewable sources (UVREGR).

Energy sales units corresponding to non-manageable special regime production (UVRENG) from non-renewable sources (UVRENGNR) and renewable sources (UVRENGR).

For power acquisition programming units, this program breakdown will include all units composed of more than one physical unit and corresponding to:

Pump Consumption Corresponding Acquisition Units (UAB).

To perform this process of disaggregation of program nominations by physical units, the OS will be able to define and communicate previously to the subject holders of programming units, the criteria, bases and codes use for the realization of these disaggregations. These criteria may be a function of the characteristics of the different programming units and may define the OS for this purpose, equivalent production units comprising a set of physical units of registered net power. less than a certain value, disaggregations by technologies, disaggregations by knots of the network model used by the OS in the security analyses, and combinations of the previous ones.

The holders of hydraulic management units (UGH) shall provide the OS with the information corresponding to the maximum total hydraulic powers per UGH which, in case they are required for safety reasons of the system, can be supplied and maintained by each hydraulic management unit for up to a maximum of 4 and 12 hours.

3.3 Offers for the technical constraint resolution process.

3.3.1 Period for the receipt of tenders. -Once the PDBF has been communicated, the OS will consider open the period of receipt of offers for the process of resolution of technical restrictions, period that will be closed 30 minutes later of the PDBF communication.

The OS will be able to extend this deadline for receipt of tenders, only in exceptional cases and after communication to all the SM through the SM Web page of the eSIOS system, communication in which the new closing time will be indicated of the period of receipt of tenders, and the specific causes on which the decision to extend the period of acceptance of tenders has been based.

3.3.2 Presentation of offers.

3.3.2.1 Energy Sales Units-The subject holders of energy sales units, associated with both market transactions and affections to bilateral contracts with physical delivery, corresponding to:

Ordinary regime production.

Non-renewable manageable special regime production.

Energy imports from external electrical systems in which a coordinated system of exchange capacity management is not in place. The existence of a coordinated system for the management of the exchange capacity will be taken into account once the Annex to Royal Decree 2351/2004 of 23 December 2004, for which Article 12 of the Royal Decree 2019/1997 is developed, is reviewed. December 26, by which the electricity production market is organized and regulated.

They will present the following offer types:

Power sales offerings that will have a character:

Required for all subjects who hold programming units that, in application of the current regulations, are obliged to make sales offers for each programming period. This obligation shall apply to all the available power in the corresponding programming unit in addition to that programmed in the PDBF, and independently of the fact that its procurement on the production market is carried out through the management of the energy programme in the daily market or through the execution of bilateral contracts with physical delivery.

The production units affected by bilateral contracts with physical delivery, the object of which is the export of energy through electrical interconnections without a coordinated system for the management of the exchange capacity, shall be submit energy sales bids for all the available power in the corresponding production unit, and this independently of the energy sales programme committed in the PDBF, as this PDBF programme, in case of a congestion in the exporting sense in such interconnection, could be reduced or even to be nullified.

Potestative for energy sales units corresponding to energy imports from those external electrical systems in which a coordinated system of exchange capacity management is not in place. The existence of a coordinated system for the management of the exchange capacity will be taken into account once the Annex to Royal Decree 2351/2004 of 23 December 2004, for which Article 12 of the Royal Decree 2019/1997 is developed, is reviewed. December 26, by which the electricity production market is organized and regulated.

Power purchase bids that will be mandatory for all sales units with respect to the energy sales program established in the PDBF for the corresponding power sales unit.

The production units of the renewable special management regime (UVREGR) and the non-manageable special regime production units (UVRENG), both non-renewable (UVRENGNR) and renewable, are exempted from this obligation. (UVRENGR), and the units of sale of energy on the market with the intention of importing from the French electricity system without the availability of capacity rights, which will not be able to present specific energy purchase offers.

3.3.2.2 Energy Acquisition Units-The holders of power acquisition units for pumping consumption, associated with both market transactions and affections to bilateral contracts with physical delivery, submit the following offer types:

Energy sales offers that will be mandatory in relation to the corresponding energy acquisition program for the pumping consumption programmed in the PDBF (reduction to the cancellation of the pumping consumption program) of the PDBF).

Power purchase offerings that will have a potestative character, for the increase with respect to the PDBF of the unit's pump consumption program.

3.3.2.3 Generic programming units (UPG and UPGSD). -Generic programming units will not participate in the resolution of technical restrictions, not accepting the submission of offers of restrictions for these generic programming units.

3.3.3 Characteristics of the tenders.-The offers for the process of resolution of technical restrictions shall be, in general, simple offers, and must be submitted by the subject holder of the corresponding unit, and (a) irrespective of whether such a unit of sale or acquisition may be partially or wholly affected by one or more bilateral contracts with physical delivery for which its execution has been communicated for the following day.

The following information will be specified for each offer:

Offer type (production, import, or pump consumption).

For each programming period, and with respect to the energy programmed in the PDBF, it will be indicated:

Power to upload:

Block N.: Divisible blocks of rising prices, in order of 1 to 10 (maximum number of blocks).

Energy (MWh).

Power price offered.

Energy to go down:

Block N.: Divisible blocks of decreasing prices, in order of 1 to 10 (maximum number of blocks).

Energy (MWh).

Power price offered.

Code for the definition of the order of precedence to consider for the impact of the possible power redispatches to be applied on a unit of consumption of pumping, and of the possible redispatches of energy to be lowered applied on a unit of sale, if the unit itself participates simultaneously in a market transaction and in the execution of one or more bilateral contracts with physical delivery (priority reduction of the programme corresponding to the market transaction and subsequent reduction of bilateral contracts by pro rata between them, reverse priority, or application of the pro rata rule over the entire transaction set.)

Power sales units for thermal power plants may present complex offers that will consist of four terms:

Revenue to keep the drive coupled for an hour.

Revenue per unit of energy produced.

Cold start revenue.

Revenue by hot start.

In the process of solution of technical restrictions these complex offers may be considered only in cases where the corresponding unit of sale of energy has a schedule null in all and each of the periods constituting the daily programming horizon, or has only one or more energy programmes in one or more of the first three periods of time of that horizon, as a downward ramp of load associated with a drive uncoupling process.

In the case of multi-axle cycles, the hot start of the complex offers may be taken into account in cases where the programme of the unit corresponds to the mode of operation of the a gas turbine and a steam turbine and, by system security requirements, that multi-axle combined cycle group is required in the technical restriction solution processes, the start of an additional gas turbine.

In cases where the complex offer is applicable, upon verification of the above condition, the use of the same shall be performed under the following criteria:

The unit will be considered to remain engaged in a given programming period as long as its production schedule is greater than zero in that period.

The term corresponding to the revenue per unit of energy produced will be specified by a single block.

Hot start: Scheduled start and/or performed by the production thermal unit so that the time interval from the last hour with the allocated program and the time the program is scheduled and/or performed the start is less than 5 hours; and the scheduled start and/or performed by the second and successive gas turbines of a multi-axis combined cycle, in response to a specific request from the OS.

Cold start: Any other scheduled boot and/or performed by the production thermal unit that does not meet the previous condition.

Subject-holders of programming units to which the submission of tenders for the process of resolution of technical restrictions apply may send offers of restrictions by default according to the provided in the operating procedure for establishing the exchange of information with the OS.

3.4 Process of solving the technical constraints of the daily operating base program (PDBF). -This process consists of two distinct phases:

FASE 1: Modifying the PDBF program by security criteria.

FASE 2: Rebalance of production and demand.

3.4.1 FASE 1: Modifying the PDBF program by security criteria.

The objective of this phase is to determine the technical constraints that may affect the execution of the PDBF, identifying those program modifications that are necessary for the resolution of the restrictions. detected techniques, and establishing the necessary security program limitations to avoid the occurrence of new technical restrictions in the second phase of the technical restriction resolution process and in subsequent markets.

3.4.1.1 Identification of technical constraints.

3.4.1.1.1 Preparation of case studies. -Security analysis for the identification of technical restrictions will take into account the following information:

The production and international exchange programs included in the PDBF.

Program breakdowns for:

Power sales units associated with multi-axis thermal power plants (UVT), hydraulic management units (UGH), and reversible pumping stations (UVBG).

Non-manageable (UVREG) and non-manageable (UVRENG) production power sales units, both from renewable sources and non-renewable sources, participating in the market through the corresponding subjects holders or representatives of the same.

The demand predicted by the OS.

The best wind production forecast available on the OS.

The best information available in relation to:

Inavailabilities both programmed and oversold that affect network elements.

Inavailabilities both programmed and oversold that affect the physical units of production and the procurement units for pumping consumption.

The demand will be considered distributed in the different nodes of the network model used by the OS for the performance of the security analyses. This distribution of the demand for knots will be performed by the OS, using the applications of the energy management systems, and the IT applications and Databases specifically designed for the analysis and the resolution of technical restrictions.

3.4.1.1.2 Technical restriction. -It is any circumstance or incident arising from the situation of the production-transport system that, due to the safety, quality and reliability of the established supply (a) Regulation (EC) No No 2014

the European Parliament and of the Council of the European Parliament and of the Council of the European Parliament and of the Council

In particular restrictions may be identified due to:

(a) Failure to comply with security conditions under permanent and/or contingency arrangements, as defined in the operating procedure establishing the operational and security criteria for the operation of the electrical system.

b) Insufficient secondary and/or tertiary regulation reserve.

c) Insufficient additional power reserve to ensure coverage of the expected demand.

d) Insufficient capacity reserve for voltage control in the Transport Network.

e) Insufficient capacity reservation for service replenishment.

For the resolution of these restrictions the mechanisms described in the present operating procedure and those other for which the management of the corresponding adjustment services of the system.

3.4.1.1.3 Security analysis.-On the basis of the above, the OS will carry out the necessary security analyses for the entire programming horizon and identify the technical constraints affecting the PDBF, the safety, quality and reliability criteria contained in the operating procedure establishing the performance and safety criteria for the operation of the electrical system.

These cases of study used for the performance of the PDBF security analyses will be made available to market subjects in RAW format of the PSS/E application after the time period has elapsed. established, where appropriate, for reasons of confidentiality of the information, as indicated in the operating procedure establishing the exchange of information with the OS.

3.4.1.1.4 Resolution of technical restrictions. -Before proceeding with the solution of the technical restrictions identified in the Spanish electricity system, the OS will resolve, if necessary, the congestions identified in the PDBF that affect interconnections with neighbouring electrical systems without a coordinated mechanism for the management of the exchange capacity, as laid down in the rules and in the operating procedures in force.

3.4.1.1.5 Resolution of technical restrictions and guarantee of supply in the Spanish electricity system. -Once verified the non-existence of congestion in the international interconnections in which a non-existent Coordinated system of management of the exchange capacity, the OS will analyze the security conditions of the Spanish peninsular electrical system and will resolve the restrictions for guarantee of supply that affect the Spanish electricity system in accordance with the procedure for the operation by which the decision of restrictions by security of supply. In the case of identifying internal technical constraints to the Spanish electrical system in the PDBF, the OS will study for each set of consecutive programming periods in which it has identified technical constraints, possible solutions that they are technically resolved by an appropriate margin of safety.

3.4.1.1.5.1 Means for the resolution of technical restrictions. -In order to resolve the technical restrictions identified in the PDBF affecting the Spanish peninsular electrical system, the OS may establish increases or reductions of the programmed energy in the PDBF.

Increased scheduled power in the PDBF:

Using the power sales offerings presented to the technical constraint resolution process by:

a) Power sales units associated with production facilities:

Units for thermal groups (UVTs).

Hydraulic management units (UGH) and reversible pumping stations (UVBG).

Non-renewable manageable special regime production units (UVREGNR).

(b) Sales units corresponding to energy imports through the electrical interconnections with Community countries (UVICs) without a coordinated system of exchange capacity management.

Reduced power programmed in the PDBF:

The reduction of the programmed energy in the PDBF for the resolution of the technical restrictions identified in the Spanish electricity system, will be carried out without direct use of offers to these effects, being considered these program reductions of the corresponding program provided in the PDBF.

These program reductions for the solution of the technical constraints identified in the PDBF may be applied to the following types of units:

a) Sales units associated with production facilities:

Units for thermal groups (UVTs).

Hydraulic management units (UGH) and reversible pumping stations (UVBG).

Managed Special Regime Production Units (UVREG) and non-manageable (UVRENG), both from non-renewable and renewable sources.

b) Sales units corresponding to energy import programmes through the electricity interconnections with Community countries (UVICs) without coordinated system of capacity management of exchange.

c) Power acquisition units for pumping consumption (UAB).

In the event that other means are not available in the Spanish peninsular electrical system, or there is a certain risk for the supply in the national peninsular territory, the reductions of the programmed energy in the PDBF may also be extended to:

(d) Acquisition units corresponding to energy export programmes through interconnections with neighbouring electrical systems (KAUs) where a coordinated system of management of the system is not in place. ability to exchange.

In exceptional situations, either by lack of means in the Spanish peninsular electricity system or by a certain risk to guarantee the supply in the Spanish peninsular territory, for the resolution of the technical restrictions identified in the PBF, the OS will be able to request the neighboring electrical systems interconnected with the Spanish electrical system, increases and/or reductions of energy programs in units located in their system.

The existence of a coordinated system for the management of exchange capacity will be taken into account once the Annex to Royal Decree 2351/2004 of 23 December 2004, for which Article 12 of the Royal Decree is developed, is revised. Decree 2019/1997 of 26 December 1997, for which the electricity production market is organised and regulated.

3.4.1.1.5.2 Selection and application of resolution media.

Solution of technical constraints by increasing the programmed energy in the PDBF. -In the case of necessary increases of the programmed energy in the PDBF, and to exist more of a technically valid solution and of Equivalent effectiveness, the OS will carry out an economic assessment of the possible solutions and choose the one that represents a lower cost. At the same cost for several equivalent solutions in terms of technical effectiveness for the resolution of the identified restrictions, the OS will select the one that represents a lower energy movement with respect to the PDBF.

Programme increases for the resolution of the technical restrictions identified in the PDBF will be carried out through the implementation of energy redispatches, resulting in new energy programmes that will be established, whenever possible, in whole MWh values, programmes which, in the case of production units, shall be of value not less than the technical minimum of the corresponding unit, nor greater than the maximum power available in the unit, power that at the limit will be equal to the net active power recorded for the same.

Program increments for PDBF that are applied for resolution of technical constraints will be valued on the basis of the offer submitted for the constraint resolution process.

In the case of multi-axle combined cycles, where the programme increases in respect of the PDBF require a change in the mode of operation of a multi-axle combined cycle leading to the start of one or more gas turbines, In addition, the scheduled and realized start of each turbine shall be considered according to the hot start of the complex offer of restrictions that has been submitted.

Solution of technical restrictions by reducing the programmed energy in the PDBF. -For the application of reductions of the energy programs provided in the PDBF for the resolution of the technical restrictions identified in the Spanish electrical system will be taken into account the influence that the energy program of each unit has on the technical restrictions identified, using to these effects the factors of contribution to the restrictions techniques obtained in the applied security analyses.

Thus, in the case of multiple units with an equivalent influence on the technical restrictions identified, the resolution of these units will reduce the programs of these units by applying the rule pro rata on their corresponding energy programmes.

In the event that the effects of the programs of these units on the identified restrictions are not equivalent, the modification of programs of the different units will be carried out, in the first place, the program of the unit which has the greatest contribution factor, respecting the minimum production schedule which may be required in this programming unit for the purposes of system security, by applying the following reductions according to the order of decreasing contribution factors obtained in the security analysis applied.

In the event that in the process of resolution of technical restrictions, congestion is identified in the evacuation of production of both ordinary and special regime, being necessary, for reasons of safety of the system, the reduction of the total production program to a certain value, the solution of the technical restrictions identified by the application of the process indicated below:

Identification in the first place of set A of sales units corresponding to production, both ordinary and special arrangements, whose contribution factor to the technical restrictions identified exceeds a certain minimum threshold.

Establishment, from the previous set, of a subset A1 consisting of each and every unit of sale of ordinary regime production (UVT + UGH + UVBG).

Reduction of the programs of the sales units that constitute the A1 subset in order of decreasing contribution factors.

Once applied to the A1 subset, the maximum reduction of programs compatible with the limitations established by reason of the security of the system, in case of persisting the situation of congestion, the OS will proceed to reduce additional production by modifying the programmes of the energy sales units corresponding to the production of special arrangements in accordance with the following order of priority, provided that the security of the system so does allow:

Non-renewable source manageable special regime production units (UVREGNR).

Renewable source manageable special regime production units (UVREGR).

Non-manageable special regime production units from non-renewable sources (UVRENGNR).

Non-manageable special regime production units from renewable sources (UVRENGR), last reducing those units whose technological adequacy, in accordance with the requirements of the operating procedures, contributes to a greater extent to ensure the security and quality of supply conditions for the electrical system.

Program reductions for the solution of the technical constraints identified in the PDBF will be made by applying power redispatches on those units.

This will reduce, first, the programs of the units with the greatest contribution, respecting the minimum production programs that may be required in these units for reasons of system security, and the order of priority referred to above in those cases where the identified technical restrictions have a contribution to both ordinary regime production units and special regime production units.

This process of reduction of programs will, in all cases, give rise to new energy programs that will be established, provided that this is possible, in whole MWh values, programs that, in the case of the units of production, shall have a value not less than the technical minimum of the corresponding unit, and shall not exceed the maximum power available in the unit, the power at the limit shall be equal to the net active power recorded for the unit.

To this end, once the energy sales programmes have been reduced in accordance with the relevant contribution factors to the identified restrictions, or the application, where appropriate, of the pro rata rule for such reduction, a rounding of those programmes shall be established by applying the International Standard ISO 31 B so that all the resulting programmes are expressed in whole MWh values.

The programme reductions for the PDBF that are necessary for the resolution of the identified technical restrictions applied to both energy sales units and procurement units (pumping consumption and, where applicable, (exports) shall be considered as cancellations of the corresponding programme provided for in the PDBF.

Solution of technical constraints due to insufficient power reserve to be raised. -In those cases where, once the redispatches have already been incorporated by guarantee of supply, according to the procedure of operation of (i) the resolution of restrictions on security of supply and, the redispatches and security constraints on the PDBF programme necessary for the resolution of technical restrictions, the existence of an insufficient reserve of power is identified; The OS will adopt the following measures in the resulting programme:

Apply minimum program limitations to a value equal to their technical minimum over all the thermal groups scheduled in the PDBF.

Apply maximum program limitations on pump consumption units.

Apply in each electrical interconnection with Community countries a comprehensive minimum programme limitation on all the programming units corresponding to energy imports through the interconnection, for a value equal to the minimum between the overall value of the set of import programmes and the value of the intended exchange capacity and published in the importing sense.

When the above measures are not sufficient to ensure an adequate margin of power reserve to be raised, the OS will schedule the start and coupling of additional thermal groups taking into account for this purpose. the power reserve to be raised that each of the available and uncoupled thermal groups would, where appropriate, contribute to the system, the minimum cold or hot start time, as the case may be, and of the programming declared by the unit (from order to up to a minimum of technical boot), as well as the cost associated with starting and programming coupling of each of them, in order to ensure the additional reserve of power to be raised with the minimum associated cost.

In this process of starting and coupling additional thermal groups, the OS will take into account the possible modes of operation of the multi-axis combined cycles.

The programming cost of a thermal group due to insufficient power reserve to be available will be calculated as the ratio between the programming cost of the group to a technical minimum at all time periods with insufficient power reserve to be raised and, the maximum available power of the group for the number of time periods in which additional thermal group programming is required.

The power reserve provided by each thermal group shall be determined according to the maximum active power available in the unit, the value of which shall be equal to the net active power recorded for that unit of the production.

For this programming of the starting and coupling of additional thermal groups due to the insufficiency of the power reserve to be made available, a specific code of redispatch will be used, preferably, to the object of be able to account individually, both the volume of these redispatches due to an insufficient reserve of power to be uploaded to the system, and the cost associated with the application of the same.

Solution of technical constraints due to insufficient power reserve to be lowered. -In those cases where, once the redispatches and security limitations on the PDBF program necessary for the (i) a reduction in the number of technical restrictions, the identification of the existence of an insufficient reserve of power to be reduced in the resulting programme, the OS may proceed to apply programme limitations on the acquisition units concerned; pumping consumption up to a value equal to that of your program in the PDBF, in order to avoid possible subsequent reductions of this pump consumption program.

3.4.1.1.5.3 Practical implementation of the resolution of restrictions. -For the establishment of the energy redispatches necessary for the resolution of the technical restrictions, the corresponding values will be respected the minimum and maximum powers of the generating groups, and the nominal powers of the pumping units, according to the information contained in the Administrative Registry of Electrical Power Production Facilities (RAIPEE) and other supplementary information (power corresponding to the minimum technical unit of production, nominal power of consumption of pumping, etc.) which, if it is not contained in the RAIPEE, shall make it easier for the OS to hold the relevant programming units in a feisty form and in accordance with the procedure laid down in the procedure for the operation of the exchanges of information with the OS. In addition, the possible transitional limitations of these power values shall also be taken into account by the subject holders of these units to the OS.

They will not be taken into consideration, on the contrary, other distinct limitations, own of each production unit, such as the maximum ramps of rise and drop of load of the thermal groups, among others, that must be managed on the intraday market, where necessary, by the holders of the relevant units.

The OS at the time of applying energy redispatches to be up on sales units corresponding to reversible pumping stations will take into account the capacity of the upper vessel of the central bank, both in terms of the feasibility of the total energy sales programme which may be required for the resolution of the technical restrictions of the PDBF, as in terms of the feasibility of the necessary pumping programme to be able to take account of that programme for the sale of energy resulting from the resolution of the technical restrictions. This pump consumption program must be established directly by the subject holder of the unit by participating in the intra-day market.

The energy increases programmed over the PDBF for the resolution of technical restrictions in the Spanish electricity system, which can be applied on sales units corresponding to energy imports through interconnections with Community countries without a coordinated system for the management of the exchange capacity shall always take into account the expected and published maximum exchange capacity values for the relevant interconnection and flow direction. The existence of a coordinated system for the management of the exchange capacity will be taken into account once the Annex to Royal Decree 2351/2004 of 23 December 2004, for which Article 12 of the Royal Decree 2019/1997 is developed, is reviewed. December 26, by which the electricity production market is organized and regulated.

Once selected, among the set of technically valid, and equally effective, solutions that represent a lower overall cost, the OS will establish, taking into account the increases of the corresponding programs the resolution of restrictions on security of supply, in accordance with the procedure for the operation of the resolution of restrictions on security of supply, the amendments to the programmes corresponding to the resolution adopted, indicating for each unit affected by such modification the type and magnitude of the redispatch which is applicable to you in a specific way, for which the following qualifications will be used:

UPO (Unit with Obtained Program):

Power sales unit for which the coupling or increase of your sales program is required with respect to the PDBF.

Pump consumption unit, or where appropriate, energy acquisition unit corresponding to an export through interconnections with neighbouring electrical systems without coordinated system of capacity management exchange, for which a reduction of its acquisition program with respect to the PDBF is required.

UPL (Limited Program Unit):

Power sales unit for which a reduction in your sales program is required with respect to the PDBF.

Energy redispatches corresponding to the resolution of technical constraints on the daily market, once incorporated into the PDVP, will be considered firm, remaining unchanged in the energy programme even in the the conditions that have resulted in the technical restriction are removed.

In all cases where the resolution of technical restrictions has associated the coupling, increase or decrease of production of specific physical units, incorporated in a given unit of sale of energy, and In addition to the programming unit concerned by the energy redispatch, the physical units and the requirements applicable to each individual unit of the energy sales unit, the OS shall define, in addition to the programming unit concerned, a total change of the programme of the energy sales unit concerned. of them in detail, incorporating these complementary data into areas (a) process of information that will be part of the exchange of information pertaining to the redispatches and security limitations communicated by the OS as part of the PDBF technical restrictions resolution process.

In cases where power redispatches are applied to a programming unit that is integrated by more than one physical unit, security constraints may also affect the same as indicated before. for redispatches, only to part of the physical units that make up the redispatch without considering, in these cases, that these limitations are necessarily applicable to the entire set of the corresponding programming unit.

In the case of the application of redispatches to be lowered on units of sale of energy corresponding to units of production or to imports, or on units of acquisition for consumption of pumping or in its case exports, By participating in the corresponding unit simultaneously in a market transaction and in the execution of one or more bilateral contracts with physical delivery, the OS will distribute the corresponding redispatch on the different transactions in which the unit is involved, taking into account the definition of the order of precedence incorporated in the tender submitted by the holder of that unit for the resolution of the technical restrictions. In the event that the said code has not been included in that offer, the priority reduction of the programme corresponding to the market transaction and the subsequent reduction of all bilateral contracts shall be considered as the default option. in which the same unit is involved by applying prorrata between them, when they are more than one.

In the case of the application of program reductions on units of purchase of pumping consumption or, where applicable, exports, associated with a bilateral physical contract, they will be applied after, in a coordinated manner, applicable, redispatches of energy to be lowered on the sales units associated with that bilateral, in accordance with the provisions of paragraph 3.4.2.1.

3.4.1.1.5.4 Setting security constraints. -As part of the technical restrictions resolution process, the OS should set limitations that are necessary for system security reasons. programmes of the different energy sales units and on the procurement programmes for pumping consumption and, where appropriate, on the programmes corresponding to energy exports through interconnections with the electrical systems neighbors.

The application of these security constraints will aim to avoid the emergence of new restrictions on subsequent processes (rebalance generation-demand, intra-day market, secondary regulation markets, and tertiary, generation-consumption diversion and real-time operation).

The OS will set these program limitations for security according to the following classifications:

LPMI (Minimum Program Limitation or Lower Limit) applicable to:

Power sales unit programmed in the PDBF and/or the PDVP where, for system security reasons, one or more of the physical units that integrate it must maintain a certain minimum energy sales program.

Power acquisition unit programmed or not in the PDBF and corresponding to a pumping consumption or, where appropriate, an export of energy through interconnections with neighbouring electrical systems, in which for reasons Your energy acquisition program cannot exceed a certain value.

LPMA (Maximum Program Limitation or Upper Limit) applicable to:

Power sales unit programmed or not in the PDBF, or programmed in the PDVP where, for system security reasons, your energy sales program cannot exceed a certain value.

Power acquisition unit programmed in the PDBF and corresponding to a pump consumption where for system security reasons its power acquisition program cannot be less than a certain value.

The allocation of security program limitations will impose restrictions on subsequent energy sales and/or energy acquisition programs for pumping consumption and, if applicable, export through the interconnections with the neighbouring electrical systems, for the programming units, or in their case physical units, on which these safety limitations have been applied.

The modification of the energy programs with respect to the PDBF, through the application of energy redispatches of type UPO (unit with program obliged) and UPL (unit with limited program), for the resolution of the restrictions identified techniques, will result in an automatic allocation of security constraints:

(a) The application of power redispatches for the assignment of a required program (UPO) over a particular power selling unit will result in the application of a minimum program limitation (LPMI), limitation that only allow the power redispatches to be applied after the unit (energy sales program increments).

(b) The allocation of a required programme (UPO) on a power acquisition unit for pumping consumption will result in the implementation of a minimum programme limitation (LPMI), a limitation which will only be applied after on this unit redispatches of energy to be raised (reductions of the power acquisition program for pumping consumption).

(c) The allocation of a limited programme (UPL) on a unit of energy sales will result in the implementation of a maximum programme limitation (LPMA), a limitation which will only allow for the implementation of this unit energy to be lowered (reductions in the energy sales program).

The application of security program limitations that set minimum program limits (LPMIs) or maximum program limits (LPMA) on the program of a power sales unit or on the consumer acquisition of pumping or, where appropriate, of export through interconnections with the neighbouring electrical systems without coordinated system of management of the capacity of interchange, will only allow the application of redispatches that respect the limits of power maximum to be lowered or raised, respectively, for them.

These program limitations established for system security reasons may disappear only in those cases where the OS removes or adjusts the corresponding security limitation applied to that unit, the situation of the system-transport system has been modified and the conditions imposing such a programme restriction are no longer present.

When minimum program security (LPMI) or maximum program (LPMA) limitations are associated with particular physical drives and not the unit of sale set, the program limitations for later security markets will also be associated with these physical units and not the energy sales unit as a whole.

In cases where the minimum program limitation (LPMI) or maximum program limitation (LPMA) affects a set of production units or a set of procurement units for pumping consumption, located in the same location, geographical area or international interconnection, the OS shall preferably establish these security constraints in a comprehensive manner, for application to a particular location, geographical area or international interconnection. These global limitations may coexist with minimum program limitations (LPMIs) and/or maximum program (LPMA) limitations applied to one or more of the units to which the global limitation affects.

When on a transient basis, due to an over-coming cause, associated with problems in the operation of the computer applications used for security analysis, or other possible causes affecting the determination and/or treatment of these global limitations, the OS will set these program limits for individual security. For the establishment of such individual limits, on the basis of a level of technical criteria, the OS will use the merit order of the tenders submitted to the technical restrictions resolution process. Irrespective of their contribution to the restriction, they shall be exempted from the application of these programme limitations, provided that the security of the system so permits, all production units of a manageable special scheme renewable (UVREGR) and non-manageable special regime (UVRENG), both from non-renewable and renewable sources.

3.4.1.1.5.5 Treatment of the resolution of technical restrictions in the Distribution Network. -In the process of resolution of technical restrictions will be analyzed and resolved the restrictions identified in the transport network, the safety, quality and reliability criteria contained in the operating procedure establishing the performance and safety criteria for the operation of the electrical system.

However, in those cases where the distribution network manager identifies the existence of a safety problem on the network under the production plan, the distribution system operator may request the OS to introduction of the modifications that are required in the PDBF to ensure safety in the affected distribution network.

In this case, the distribution system operator shall communicate to the OS, in accordance with the operating procedure for the exchange of information with the OS, the existing risk in the distribution network which is the object of its operation. management, the days and periods of programming affected, the measures to be taken, and the changes required in the production programmes, in the event that they are necessary. In this communication, the distribution system operator must explain in detail those requirements, the risk existing in the distribution network and the impossibility of adopting other alternative measures (topological measures or application of the the contracts for the sale of energy by the undersigned with the holders of the production facilities under special arrangements, among others) which could avoid, or at least reduce, the introduction of modifications to the daily base programme intended operation.

In cases where the distribution system operator identifies the existence of restrictions on the network which is the subject of its management as a result of the scheduling of a discharge on the transport network or on the network of distribution, such a manager must communicate this fact to the OS as far as possible, in order to enable such information to be part of the communication of network inavailabilities with influence in the production program that the OS communicates each day prior to the daily market, in accordance with the provisions of the operating procedure for the that information exchanges with the OS are established.

In cases where the above is not possible, for unwanted delays in the communication of such information, or other unanticipated causes, or where the technical restriction is directly associated with the plan itself (a) the distribution network operator must inform the OS of the existence of such a technical restriction before 13:00 hours of the day on which the programming is carried out and, in any event, before the end of the day of the publication by the OS of the energy redispatches and the necessary limitations for safety reasons for the resolution of the technical restrictions identified in the PDBF, so that these additional modifications to the PDBF programme can also be taken into account in the process of re-balancing generation-demand.

According to this information, the OS will introduce the required modifications to the PDBF and inform the distribution network manager of the introduction of these redispatches and program modifications. associated, as well as program limitations applied to the security of the distribution network.

For these redispatches and safety limitations applied to the PDBF program for safety reasons of the distribution network, the OS will, preferably, use specific codes in order to be able to establish precisely, their volume, as well as the costs associated with them.

3.4.1.1.5.6 Treatment of the congestion identified in the generation evacuation. -When in the process of resolution of technical restrictions a situation of congestion due to an excess of production is identified in a a zone with regard to the capacity for evacuation of the same, depending on whether such congestion is already identified in the case-study basis, or that it appears only in the case of certain contingencies, that it will be carried out as indicated below:

a) Condemarches in the case of study and/or identification of conditions of transient post-contingency instability.

Production shall be limited in the area affected by congestion in such a way that at no time on the evacuation lines and transformers the maximum load limits set in the operation procedure shall be exceeded. the operating and security criteria of the system operation.

This same performance will be carried out in cases where, in the event of contingency, dynamic analyses show the existence of situations of transient instability in a certain area of the electricity system. is weakly attached to the rest of the system or, even at the extreme, practically isolated from it, with a strong production-demand imbalance in the area, which would put the security of supply at risk in the area.

The reduction of the energy programme with respect to the PDBF of the units whose contribution to the identified technical restrictions exceeds a certain minimum threshold shall be made on the basis of their contribution to the restriction the identified technique, taking into account the criteria already mentioned in paragraph 3.4.1.1.5.2.

Thus, in the case of several units whose contribution to the identified technical constraints is equivalent, the energy to be reduced among all of them will be extended according to their planned programme in the PDBF, and in the Other cases for the implementation of these programme reductions shall be taken into account for the factors contributing to the restriction referred to above.

In this process of reducing the energy program with respect to the PDBF, the technical minimum of the thermal groups will be respected. If, once the production of all the groups involved in the congestion has been reduced to the technical minimum, an excess of production will persist in the area, the stop of thermal groups will be programmed, according to the order of merit of the energy purchase offers (reduction of the PDBF programme) submitted for the process of resolution of technical restrictions by the holders of those sales units, initiating the scheduling of the stop of those units which have submitted a higher price on your power purchase offer.

When matching offers at the same price, the thermal group stop will be programmed based on their technical minima, starting with that group with a higher technical minimum, provided the safety of the electrical system so allows it.

In this process of scheduling the stop of thermal groups, the minimum cold start and programming time of the unit (from boot order to technical minimum) must be taken into account, thus being programmed in first place the group stop with a shorter start and/or programming time.

In the particular case where a congestion situation is identified in the production evacuation in which several units belonging to the same SM are involved with a contribution equivalent to congestion, it shall be prorated preferably the energy to be reduced for the congestion solution between the sum of the PDBF program of all the production units belonging to the same SM, and the order of priority communicated to the OS by the corresponding SM will be taken into account for their units when applying the reduction of programs to the production units of each subject, in accordance with the provisions of the operating procedure establishing the exchange of information with the OS and, provided that the security of the system so permits.

The production of special arrangements will also intervene in the resolution of these technical restrictions, in the event that the security of the system so requires, once already reduced to the minimum values compatible with safety of the system, the production schedules of the ordinary system units, following in this process the different phases described in paragraph 3.4.1.1.5.2. of this procedure.

b) Condemarches in post-contingency situations.

Once there is no evidence of the existence of congestion in the case study, or of conditions of temporary instability that require a priori reduction of production in the area, having already been resolved Case, they would have been identified, then the possible existence of post-contingency congestions will be analyzed.

In the event of such congestion detection, your resolution will be analyzed by adopting corrective measures that will only apply in case of contingencies that cause technical constraints.

Where the adoption of post-contingency corrective measures is not possible, or the implementation of these measures requires a time higher than the time allowed for the consideration of transient overloads in transport elements, In accordance with the procedure laid down in the operating procedure laying down the criteria for operation and safety for the operation of the system, the necessary preventive measures shall be laid down, by means of the reduction of the units of production in the area, applying the same criteria as above for the resolution of congestions in the base case.

c) Teleshots in production units.

In the case of congestion in the production evacuation of a zone limited to post-contingency situations, the production units that may be affected by a reduction, or even by the preventive annulment of the the energy programme envisaged for them in the PDBF, will be able to avoid, or at least reduce, this decrease in their programme, by activation, after authorization by the OS, of a generation tele-firing automatism acting in case of present any of the contingencies that cause unacceptable post-contingency overloads. These automatic generation-firing automatisms may result in the disconnection of the production unit and the complete loss of production of the unit, or a rapid and partial reduction in the production of the unit without disconnection from the production unit. same.

The above will be applicable as long as these tele-firing automatisms act with the required response speed, meet the technical conditions set and are thus enabled by the OS to perform this function, the safety of the electrical system is guaranteed at all times.

In cases where the congestion solution requires the activation of a number of remote-generation tele-firing automatisms to the existing ones, for activation of the same the OS will establish a shift system rotating in the definition of which the holders of the production units of the area provided with telephoto systems may take part.

In the event that the activation of a tele-shot allows to avoid the reduction of the production schedule by such a amount that the reduction requested of the unit that activates said telephoto is exceeded, said additional margin Production will be distributed among the remaining units of production, giving preference to those units which, having a remote-firing system, have not been required, however, the activation of the system is not necessary.

The subject holder of each programming unit shall communicate to the OS, without delay, any change or modification that may affect the operation or operation of these telefiring automatisms.

d) Application of limitations to avoid congestion in later markets for increased production with respect to the PDVP.

In the event that there are no congestions in the baseline case or in post-contingency situation with the energy sales programs in the PDBF corresponding to these production units, but these congestions could if the production units in the area increase their production in subsequent markets (intra-day market, diversion management and tertiary regulation), on top of a certain value, the OS will proceed as follows:

It will determine by horariously, what is the maximum production value that can be allowed in the zone, identifying whether the restriction would be presented only in post-contingency situation, or whether it would correspond to a congestion in the case base.

If possible congestion is identified only in post-contingency situation, it will be determined what is the maximum allowable production value in the area taking into consideration the teleshots of the area groups, these assumptions groups with the same PDVP energy programs.

Once established in both cases the maximum production increase over the programs provided in the PDVP, acceptable for system security reasons, the additional capacity value available (whichever is more In the case of a limited number of groups in the area with influence on congestion, it will be allocated, preferably in the form of a zonal limitation, and alternatively, in the form of an individual limitation on each group of the zone with influence on the congestion, according to order of increasing prices of the offered offers for the process of resolution of technical restrictions by the holders of these energy sales units. In the case of equal price in the offers of two production units, the allowable production increases shall be established by giving preference to the operation of those groups for which their corresponding systems of production have been activated. teleshooting.

3.4.1.1.5.7 Treatment of program modifications requested by the neighboring electrical systems. -The transmission system operators of neighboring electrical systems interconnected with the Spanish electricity system will be able to ask the OS for the introduction of the modifications that are accurate in the PDBF to ensure security on your network.

In this case, the transmission system operator of the neighbouring electricity system shall be directed in writing-by fax or e-mail-to the OS, informing it of the risk on the transport network which is the subject of its management, and detailing in addition, the days and periods of programming affected, the measures to be taken, and the modifications required in the production programmes, in the event that they are necessary. In this communication, the transmission system operator of the neighbouring electricity system must provide a detailed justification for these requirements, the risk on its network and the impossibility of taking other alternative measures (topological measures or modification of programs in units of their electrical system, among others) that could avoid, or at least reduce, the introduction of requested program modifications.

This information must be communicated by the transmission system operator of the neighbouring electrical system to the OS as far as possible and, in any case, prior to the publication by the OS of the redispatches of energy and the constraints necessary for security reasons for the resolution of the technical restrictions identified in the PDBF, so that these additional modifications to the PDBF programme can also be taken into account in the Generation-demand rebalancing process.

According to this information, the OS will introduce the required modifications to the PDBF and inform the transmission system operator of the electricity system of the introduction of these redispatches and the associated program modifications, as well as program limitations applied to the security of your transportation network.

For these redispatches and safety limitations applied to the PDBF program at the request of the neighboring electrical system, the OS will use, preferably, specific codes to the object of being able to establish with precision, both its volume, such as the costs associated with them which will be borne by the neighbouring electricity system which has made the corresponding application.

3.4.2 PHASE 2: Reequilibrium generation-demand.-Once the technical restrictions identified in the PDBF have been resolved and, where appropriate, the restrictions for security of supply in accordance with the operating procedure whereby the resolution of restrictions by guarantee of supply is established, the OS will proceed to make the necessary modifications of program in order to obtain a balanced program in generation and demand, respecting the limitations established, system security reasons, in the first phase of the resolution process technical constraints, and the expected and published values of the exchange capacity in international interconnections.

3.4.2.1 Partial or total reduction of the energy sales programmes for bilateral contracts with physical delivery the demand for which has been reduced in PHASE 1.

The OS will first proceed to partially or even totally reduce the energy sales programs of those programming units that are enabled to participate in the restriction resolution process. (a) technical, bilateral contracts with physical delivery whose corresponding demand has been reduced in the first phase of the PDBF technical restrictions resolution process.

According to the provisions of the first phase of the PDBF technical restrictions resolution process, this demand will correspond to pumping consumption units and, when there are no other means to resolve the restrictions or there is a certain risk for the supply in the national peninsular system, to units corresponding to export transactions through the interconnections with the neighbouring electrical systems in which a coordinated system of management of the exchange capacity. The existence of a coordinated system for the management of the exchange capacity will be taken into account once the Annex to Royal Decree 2351/2004 of 23 December 2004, for which Article 12 of the Royal Decree 2019/1997 is developed, is reviewed. December 26, by which the electricity production market is organized and regulated.

In the event that the energy sales program associated with that bilateral contract has also been reduced as a result of the solution of restrictions in the first phase of the process, the OS will determine such a reduction. by comparing the following values:

Decrease (D) required in the unit of sale program by the first phase of the technical constraint resolution process.

Partial or total reduction (R) of the unit of sale program associated with the rebalancing of the bilateral contract with physical delivery after the reduction of the acquisition unit program in the first phase of the technical constraints.

This way:

If the decrease (D) is greater than the reduction (R):

The energy sales unit program will be cancelled in accordance with the reduction of the reduced acquisition unit program in PHASE 1 (R) (ECOCBV redispatch).

The difference between the decrease (D) and the reduction (R) will generate a power redispatch to be lowered (D-R) that will be applied on the unit of sale, as a consequence of the resolution of technical constraints by safety criteria (redispatch UPLPVPV).

If the decrease (D) is lower or the limit equal to the reduction (R):

The energy sales unit program will be cancelled in accordance with the reduction of the acquisition unit program applied in PHASE 1 (R) (ECOCBV redispatch).

No power will be generated to be downloaded to the sales unit.

3.4.2.2 Partial or total reduction of energy acquisition programmes corresponding to a pumping consumption or an export through interconnections without a coordinated system of exchange capacity management associated with bilateral contracts with physical delivery the generation of which has been reduced in PHASE 1.

The OS will reduce, or even cancel the energy acquisition programs corresponding to pumping consumption or to exports through interconnections without coordinated system of management of the capacity of exchange which are associated with bilateral contracts with physical delivery, the corresponding generation of which has been reduced in the first phase of the PDBF technical restriction resolution process. The existence of a coordinated system for the management of the exchange capacity will be taken into account once the Annex to Royal Decree 2351/2004 of 23 December 2004, for which Article 12 of the Royal Decree 2019/1997 is developed, is reviewed. December 26, by which the electricity production market is organized and regulated.

In the event that the energy acquisition program associated with that bilateral contract has also been reduced as a result of the resolution of restrictions in the first phase of the process, the OS will determine that reduction by comparing the following values:

Decrease (D) required in the acquisition unit program by the first phase of the technical constraint resolution process.

Reduction (R) of the acquisition unit program associated with the rebalancing of the bilateral contract with physical delivery after the reduction of the unit of sale program in the first phase of the technical restrictions process.

This way:

If the decrease (D) is greater than the reduction (R):

The energy acquisition unit program will be cancelled in accordance with the reduction of the reduced unit of sale program in PHASE 1 (R) (ECOCBV redispatch).

The difference between the decrease (D) and the reduction (R) will generate a power re-dispatch (D-R) that will be applied on the acquisition unit, as a result of the resolution of technical constraints by criteria of security (UPOPVPB redispatch).

If the decrease (D) is lower or the limit equal to the reduction (R):

The energy acquisition unit program will be cancelled in accordance with the reduction of the reduced unit of sale program in PHASE 1 (R) (ECOCBV redispatch).

No power will be generated to be downloaded to the sales unit.

3.4.2.3 Obtaining a balanced program generation-demand.

Means for the balance generation-demand.-To restore the balance generation-demand, the OS may proceed to the allocation of the simple offers presented and accepted for the process of resolution of restrictions techniques for the increase or reduction of the programmed energy in the PDBF by the holders of the following types of units:

a) Power sales units associated with production facilities:

Units for thermal groups (UVTs).

Hydraulic management units (UGH) and reversible pumping stations (UVBG).

Non-renewable manageable special regime production units (UVREGNR).

Non-manageable special regime (UVREGR) and special regime (UVRER) production sales units will not participate in this process.

b) Sales units corresponding to energy imports through interconnections with neighbouring electrical systems without a coordinated system of exchange capacity management (UVI (interconnections with systems) Community electricity and third countries). The existence of a coordinated system for the management of the exchange capacity will be taken into account once the Annex to Royal Decree 2351/2004 of 23 December 2004, for which Article 12 of the Royal Decree 2019/1997 is developed, is reviewed. December 26, by which the electricity production market is organized and regulated.

(c) Units of sale of energy on the market with the intention of their import from the French electricity system without having capacity rights, will not participate in this process.

d) Power acquisition units for pumping consumption (UAB).

The bidding blocks to be allocated will, if any, be the following for those already used in the security criteria constraint resolution process.

Selection and application of the means for generating-demand rebalancing.-The OS will determine the modifications to be made to the daily program base of operation (PDBF), after the inclusion of the modifications established in the first stage of the process of resolution of technical restrictions which have not been compensated in the process of the resolution of restrictions by security of supply, in accordance with the procedure for the resolution of restrictions for security of supply, in order to obtain a balanced programme in generation and demand in each and every programming period, with the view that these modifications have the least possible economic impact, and in all cases respect the safety programme limitations set out in the first stage of the process and the capacity of exchange in international interconnections.

In case it is necessary to resolve in this phase an excess generation created in the first phase, the OS will determine the units that will be modified its program according to the application of the following criteria:

Allocation of program modifications, first of all, to those units that are required to submit energy offers to be lowered for the process of resolution of technical restrictions, have not been addressed obligation:

In case the modification, compatible with the compliance of the safety criteria, of the programs of this set of units that have not attended to the requirement to present their offers to the OS, exceed the needs In order to reduce energy demand, the programme modifications will be distributed among them by means of a pro rata distribution among all of them.

In the event that after the modification of each and every one of the programs of the units that have not attended to the requirement to present their offers to the OS, still persist a certain imbalance generation-demand, the OS will proceed to the allocation of the energy purchase offers for the reduction of the PDBF programme submitted to the process of resolution of technical restrictions, offers to be allocated according to decreasing offer prices and taking into account the point of operation of the unit.

In the event that a generation deficit resulting from the modification of programmes in the first phase needs to be resolved at this stage, the OS will determine the units that will be modified by the programme according to the implementation of the programmes. following criteria:

Allocation of program modifications, first, to those units that are required to submit energy offers to be uploaded for the resolution of the technical restrictions, have not yet presented these offers:

In case the modification, compatible with the compliance of the safety criteria, of the programs of this set of units that have not attended to the requirement to present their offers to the OS, exceed the needs (i) energy to be increased for the generation-demand rebalancing, the programme modifications will be distributed among them by a pro rata distribution among all of them.

If after the modification of each and every program of the units that have not attended to the requirement to present their offers to the OS, still persist a certain imbalance generation-demand, the OS will proceed to the the allocation of the energy sales offers (increase of the programme of the sales units and/or reduction of the programme of the procurement units corresponding to the pumping consumption) submitted to the process for the resolution of technical restrictions, offers to be allocated based on growing offer prices.

In both cases, if at the end of the assignment there was a price match on more than one offer, not being able to be fully allocated said set of offers of the same price, the allocation will be made by a distribution to prorrata between that set of offers of the same price.

In this apportionment, only the technical minima of those units on which they have been applied, for reasons of system security, minimum program limitations (LPMI), will be respected.

Once a balanced generation-demand programme has been obtained, the OS will proceed to the publication of the provisional Viable Daily Programme (PDVP), in accordance with the schedules set out in the operating procedure under which the programming of the generation.

3.5 Inavailabilities of production units with influence on security, reported after the PDBF was published. -In the case of partial or total unavailability for the programming day of a unit of scheduled or limited production for the PDBF's resolution of restrictions, if the communication of such unavailability is made before 13:00 hours of the day on which the programming is made, the OS will try to readjust the program provided for the resolution of the restrictions of the PDBF, according to the latest information available at relationship to generation inavailabilities.

If the unavailability communication is received after 13:00 hours, or if it is still known before that time, the reported unavailability affects the resolution of the PDBF restrictions in a As such that the consideration of the same could delay the publication of the PDVP beyond 14:30 hours, the OS will proceed to publish the PDVP without considering such inavailability of generation, addressing the resolution of the technical restriction associated with the existence of this unavailability, once the PDVP has been published.

In order to establish the solution of the technical restrictions, the OS will take into account both the inavailabilities that have been communicated to it by the respective subject holders of programming units through the registers of unavailability, such as other information that has been transmitted to it by the subject holders through other possible means of communication provided with systems of registration.

Once the unavailability of a production unit has been declared, and the unavailability of the PDBF technical restriction resolution process has been taken into account, it has not been applied to this unit. redispatches or program limitations for security, the subject holder of the unit may go to the intraday market and/or participate, if necessary, in a diversion management session to buy back the energy program provided in the PDBF and not can produce, in order to avoid incurring a detour in front of its PDBF program.

In the event that to avoid major delays in the release of the PDVP, the OS has maintained security limitations, and in its case redispatches of power over a production unit for which the holder has communicated an unavailability for the next day, the OS immediately after the release of the PDVP will proceed to enter the detour log for unavailability on the program of said unit, according to the records of unavailability sent by the titular holder, remaining unchanged the limitations by security applied to that unit.

In case of an advance of the availability of the unit on the schedule initially planned, the OS will proceed to the elimination of the log by the declared unavailability, maintaining the unit the program PDVP established for the resolution of the technical restrictions of the PDBF, and the security constraints associated with such programming.

In the event that this advance of the unit availability on the schedule initially planned, occurs however after the production unit has reduced, or even, reached to cancel the affected program by the unavailability by its participation in the intra-day market, or in a call for management of deviations, that production unit may only participate in the programming through the submission of tenders on the market intra-day or, if applicable, a detour management session.

3.6 Information to the OM and market subjects. -As a result of the PDBF's technical restrictions resolution process, the OS will make available to the OM and market subjects, as set out in the the procedure for establishing the exchange of information with the OS, the following information:

Information that the OS will make available to the OM:

The security constraints applied to the programs of the sales and energy acquisition units to prevent further technical constraints from being generated in subsequent processes and markets.

The PDVP Interim Viable Program.

Information that the OS will make available to market participants:

The above information made available to the OM.

Energy redispatches applied on the units affected to international bilateral contracts included in the PDBF, resulting from the auction of exchange capacity for the resolution of the identified congestions, where appropriate, in those international interconnections where a coordinated capacity management system is not in place.

The hourly marginal prices resulting from the exchange capacity auctions between international bilateral contracts with physical delivery, applied in those international interconnections in which it is not implemented a coordinated capacity management system.

Energy redispatches applied on market transactions corresponding to imports and/or exports of energy with neighbouring electrical systems, for the solution of congestion in interconnections International interconnections identified in the PDBF in those international interconnections where coordinated capacity allocation systems are not deployed.

The redispatches applied to the programs of the sales and energy acquisition units to resolve the technical constraints identified in the PDBF, associated with both market transactions and contracts bilateral.

The redispatches applied to the sales and energy acquisition units for the generation-demand rebalancing, associated with both market transactions and bilateral contracts.

The OS will also make available to the OM and/or the market subjects any updates to the files previously made available to them in the process of resolution of technical restrictions that has been required.

These exchanges of information will be carried out through the means and with the structure defined in the current versions of the procedure established for the exchange of information of the OS with the subjects of the market and the the joint procedure agreed between the OS and the OM.

3.7 Failure and complaint resolution regarding the resolution process of the PDBF technical constraints. -The possible identification of anomalies and/or claims submission to the restriction resolution process The PDBF techniques could lead to the repetition of this process in case the solution of the anomaly so makes it necessary, provided that this is possible, with due respect to the maximum permitted time limits established and published by the OS, to ensure that the subsequent processes of the programming of the generation.

Once the PDVP or any of the information media associated with the resolution of the PDBF technical restrictions has been published, the subject holders of the programming units may submit claims to this process, within the time limit set in the operating procedure by which the generation programming is established, by means of the Application of Claims Management made available to these effects by the OS, and may advance the information concerning the existence of this claim, by telephone, fax or electronic mail, where necessary, in any event, the existence of a formal communication expressed through the application of the IT application of claims management, or by a written means (fax or e-mail), for its consideration as formal claim.

4. Resolution of technical restrictions on the intra-day market.-The OS will communicate with the PDVP each day and in accordance with the procedure for the exchange of information with the OS. security constraints applicable to both individual programming units and, where appropriate, sets of programming units (zonal constraints), which are to be considered applied on the programmes of the production units, and in the case of importation, and the programmes of the pumping units and, where appropriate, exports, not to modify the intended system security conditions.

Throughout the day, the OS will modify these security limitations, and/or incorporate new ones, according to the actual situation of the existing system at any time.

The OS will make available to the OM, before the opening of each session of the IM, the information regarding the security limitations so that these can be taken into account in the process of acceptance of offers of each of the intra-day market (MI) sessions, in the case of security constraints applicable to individual programming units, or within the internal market appeal process itself, in the case of security constraints applicable to the a set of programming units.

Once the outcome of the appeal of each session of the IM is communicated by the OM, the OS shall receive the nominations of programs per unit of programming, in those cases where in the same unit of offer are integrated two or more programming units.

The subject holders of programming units shall provide the OS with the information corresponding to the disaggregations in physical units and/or equivalent production units of the sales and acquisition programmes of the energy, contracted or adjusted in that session.

4.1 Reception and loading of the outcome of the appeal from the IM. -As a step before the implementation of the security analysis, the OS will verify that the program resulting from the appeal of offers in the relevant market session Intraday respects the ability to exchange international interconnections, as well as the security program limitations established by the OS and made available to the OM prior to the opening of the corresponding IM session they are respected, or at least do not keep the solution of their compliance away. If the above does not apply, the OS shall return to the OM, where appropriate, the programme resulting from the appeal of tenders in the IM.

In the event that the obtaining of a program that does not present congestion in the international interconnections was delayed for a time such that it could be affected very important the programming process itself of the generation, there is a high risk of having to suspend the application of the results of that session of the intraday market in some hour, the OS will proceed to solve these congestions, whenever possible, in the own process of solution of technical restrictions of the intra-day market.

4.2 Process of resolution of technical restrictions of the intraday market. -The OS, in case of identification of any technical restriction that prevents the program resulting from the session of the intra-day market, having also in the programme nominations per unit of programming communicated by the subject-holders, shall be carried out in compliance with the safety and operational criteria laid down in the relevant operating procedure; selecting the set of offers to be removed that resolve the constraints On the basis of the order of economic precedence of the offers married in the intraday market communicated by the OM, provided that the withdrawal of such offers can be compensated by the withdrawal of other married offers in the same session and also located in the Spanish electricity system, in such a way that it is possible to obtain a balanced program in generation-demand.

The general-demand balance will be re-established by the withdrawal by the OS of other tenders submitted to the intra-day market session, in accordance with the economic precedence of the offers allocated in the that session.

As a result of the process of resolution of technical restrictions on the intraday market, the OS will make available to OM and market subjects the following information:

Information that the OS will make available to the OM:

The Final Schedule Program (PHF) established by the OS as a result of the aggregation of all firm transactions formalized for each programming period as a result of the daily viable program and the Intra-day market after resolution, where applicable, and whenever possible, the technical restrictions identified and the subsequent rebalancing.

Information that the OS will make available to market participants:

The above information made available to the OM.

The power redispatches required to resolve the identified technical constraints.

The power redispatches needed for the subsequent rebalancing of production and demand.

The publication of the Final Schedule Program (PHF) will be performed according to the schedules set in the operation procedure that establishes the generation schedule.

The OS will also make available to the OM and/or the market subjects any updates to the files previously made available to them in the process of resolution of technical restrictions that has been required.

These exchanges of information will be carried out through the means and with the structure defined in the current versions of the procedure established for the exchange of information of the OS with the subjects of the market and the the joint procedure agreed between the OS and the OM.

5. Resolution of technical constraints in real time.

5.1 Changes by security criteria. -The OS will permanently analyze the state of the system's actual and anticipated security throughout the entire programming horizon and detect any restrictions that may exist. in each programming period. The resolution of the restrictions will cover the entire programming horizon even if only the energy redispatches will be incorporated in the existing programming periods until the beginning of the programming horizon of the next session of the Intraday market. For the remainder of the period, the necessary limitations for safety reasons shall be established: zonal limitations applicable to a set of individual programming units and/or limitations applicable to a unit of sale or to a unit of energy acquisition, or, to one or more of the physical units that make up the unit.

For the establishment and real-time updating of the safety limits necessary for the resolution of technical restrictions, the same criteria as referred to in paragraph 3.4.1.1.5.2. of the (a) this procedure, thus respecting the values corresponding to the minimum and maximum technical powers of the generating groups and the possible transitional limitations of these power values, without considering any other limitations, such as maximum ramps for loading and lowering the load of the thermal groups, between other, as long as they can be managed on the intraday market by the subject holders of the programming units corresponding to those groups.

Thus, the OS will only program the ramp up/down load of production thermal units when the resolution of technical constraints has been programmed for a programming period such that the subject holder of such a programming unit has no effective possibility to participate in the intraday market session corresponding to the incompatibility of the schedules of that session and the programming period for which the change of the programme of the programming unit for the resolution of the technical restrictions identified in real time.

For the resolution of a real-time technical restriction requiring modification of one or more units ' generation programs, the OS will adopt the resolution representing the minimum cost, using the Tertiary regulation offers that are available at that time.

In the event that the allocation of tertiary regulation offers for the resolution of the restriction is insufficient, this allocation will be supplemented by the allocation of increases and reductions in programmes under the the allocation of the tenders and/or the corresponding offer blocks submitted for the PDBF technical restrictions resolution process, and where applicable, the offer of updated restrictions, with the allocation of the latter modification of programs among the set of units that resolve the constraint, according to the price order of the tenders submitted, the pro rata rule being applied in the case of an equal bid price. In this process of allocation of the offer of restrictions presented, the complex offer may be considered only in cases where the corresponding unit of sale of energy has a zero final schedule in all and each of the periods constituting the programming time horizon, or it has only energy programme in the first three periods of time of the horizon, as a downward ramp of load associated with a process of uncoupling the unit.

In cases where the allocation of programme increments requires a change in the mode of operation of a multi-axle combined cycle leading to the start of one or more gas turbines, the start shall be considered programmed and made of each turbine according to the hot start of the complex offer of restrictions that has been presented.

From 16:00 hours of day D-1, market subjects may proceed to continuously update for day D, the offers of restrictions presented for the PDBF technical restrictions solution process, a the necessary IT applications are developed and in accordance with what is established in the procedure for the exchange of information with the OS. The OS may delay the opening time for the update of tenders when there are delays in the markets that make it necessary. The SM will be informed through the SM Web of the eSIOS.

In the event that the solution of the real-time restriction requires a reduction in production, inter alia, inter alia, renewable and non-manageable managed special regime production units, these units of production shall maintain its programme without modification, except where the security of the system so requires, once it has been reduced to the minimum values compatible with the safety of the system, the programmes of the other production units intervening in that restriction and taking into account the order of priority set out in the paragraph 3.4.1.1.5.2 of this procedure.

In the event that to ensure system security is accurate the activation of telephoto during the operation in real time, it will apply, if any, the system of rotating shifts established, or in its absence, used as an order criterion to require its activation, that of the tenders submitted for the process of the solution of technical restrictions of the PDBF, except in the case of special regime production, for which activation is required of the telephoto system, only last and following the order of priority set out in the 3.4.1.1.5.2 of this procedure.

The energy redispatches corresponding to the resolution of technical restrictions in real time that have not been effectively executed, will not be considered firm, that is, they will be able to leave without effect the allocations not yet executed when the conditions that gave rise to such a technical restriction are removed.

In cases where the distribution system operator identifies in real time the existence of restrictions on the network which is the subject of its management, in order for the solution to be modified, the production programmes envisaged must be modified. The information referred to in paragraph 3.4.1.1.5.5 of this procedure shall be communicated to the OS, as soon as possible, by all the measures at its disposal by the distribution system operator, as soon as possible.

When the transmission system operator of an electrical system interconnected with the Spanish peninsular electrical system identifies in real time the existence of restrictions in the network object of its management, for which solution It is necessary to amend the production programmes provided for in the Spanish electricity system, once all the measures at its disposal have already been adopted by the neighbouring electricity system, it must inform the OS as soon as possible of the information identified in the Paragraph 3.4.1.1.5.7 of this procedure. The OS shall also proceed as set out in that paragraph of this procedure.

5.2 Treatment of the reductions/cancellations of the capacity to evacuate the production of generating groups for over-sold inavailabilities of elements of the Transport Network or of the Distribution Network. -In the case of Due to a breakdown or a fortuitous unavailability is reduced or prevented the ability to evacuate the production of a generator group, being the group available and operating in real time, the OS will proceed to solve the congestion identified in real time by the implementation of a power redispatch on the planned programme for the unit, in such a way that this reduction or cancellation of the evacuation capacity does not involve a diversion of the actual production of the unit in relation to the programme envisaged for the unit.

This redispatch will apply from that moment when the capacity for evacuation is affected until the moment when this capacity is already partially or totally restored, proceeding in the first case the OS to adapt the the program of the unit so that it conforms to the actual available evacuation capacity.

In the case of thermal groups, the limitation or, where appropriate, the cancellation of the program of the unit shall be maintained, if necessary, after the capacity of evacuation has been restored, for a period of time equal to the minimum time hot start declared by the unit (from start to sync), or at most, to the start of the application horizon of the next session of the Intradiary Market, in order to allow the unit to recover its program or at least manage the modification of the program in an intraday market session.

5.3 Resolution of restrictions due to insufficient reserve of power to be lowered. -When during the operation in real time the existence of an insufficient reserve of power is identified to be reduced in the resulting program, the OS may take the following measures:

Increase the power program of the procurement units for pumping consumption.

Reduce the production schedule of energy sales units for thermal groups up to their minimum allowable power, for safety, or at the limit up to the technical minimum of the unit.

Schedule the stop of thermal groups while respecting the minimum program limitations established by security on the groups and, taking into account the start and programming time of each group. On the basis of technical criteria, the OS will establish a rotating shift system to schedule this stop of thermal groups per reserve of power to fall short.

In the event that the above measures are not sufficient to ensure an adequate margin of power reserve to be lowered in the system, the OS will proceed to reduce the production program of energy sales units. corresponding to the production of a special arrangement, up to its minimum permissible power by security, or in the limit up to the technical minimum of the unit, in accordance with the following order of priority:

Special regime production units manageable from non-renewable sources.

Special regime production units manageable from renewable sources.

Non-manageable special regime production units from non-renewable sources.

Non-manageable special regime production units from renewable sources.

5.4 Resolution of restrictions by action on demand. -When during the operation in real time it is not possible to resolve a technical restriction whose solution requires an increase of program of the units production, because these resources have been exhausted or require excessive time, the OS will have to resolve the restriction, or at least alleviate it, by adopting the following measures applied to the demand. This will follow the following order:

Reduction/cancellation of the pumping consumption that might be coupled in the zone.

Reduction/cancellation of export capabilities to other external systems external systems without coordinated mechanism of exchange capacity management and, in case of force majeure, external systems with mechanism coordinated management of the exchange capacity ..

Application of interruptibility to clients with this type of contract, including what is foreseen in the operating procedure by which the operating measures are established to ensure the coverage of the demand in situations Warning and emergency.

Within each category, market criteria shall be applied, whenever possible, conditional on the compatibility of the time required for the application of each of these measures.

Reduction of pumping consumption. -For the use of pumping consumption units to solve technical constraints identified in real time, the order of economic precedence of the offers of tertiary regulation to be submitted to the OS by the holders of such units, provided that there is no technical condition preventing the consideration of such an order.

Application of reduction/cancellation of export capacities. -In the event that the above measures prove insufficient, and in the area there are energy export programs through interconnections with the Neighbouring electrical systems, the OS will proceed to the /cancellation of the export capacity.

The operator of the affected neighbouring system will be notified of the reasons for the modification of the swap capacity, the new export capacity value being agreed between the two operators, as well as the hour and minute of the establishment of the new global exchange programme in the adjustment of the frequency-power system regulator regulating the exchange of electricity in such interconnection and, where appropriate, the new exchange programmes authorised in the two senses of flow.

The new exchange capacity will be published in the SIOS, adapting it to the physical reality of the electrical system, and information will be provided on the reasons for the modification.

Reducing export capacity will result in:

Coordinated balance sheet action in those interconnections with coordinated management mechanism, except in case of force majeure, to ensure the intended export programmes.

Reduction of planned exchange programmes, by pro rata, in case of interconnections without coordinated mechanism or in case of force majeure.

Application of the demand interruptibility system. -The OS will determine the application of the appropriate demand interruptibility to the existing operating circumstances, in terms of type, duration, power and scope of application.

The OS will inform the Management Authority with powers in terms of energy, the NEC and the affected market subjects, on the order of interruptibility given and the reasons for its application.

5.5 Reequilibrium generation-demand after the resolution of technical constraints in real time. -In the process of solving technical restrictions in real time, after the modification of programs by criteria of Security, no systematic process of rebalance generation-demand is established. The possible generation-demand imbalances caused by the real time resolution of the identified restrictions will be resolved, along with the other deviations communicated by the subject holders of programming units, the deviations between the actual and the expected demand for the OS, and the deviations between the actual and the expected wind production, by the use of secondary and/or tertiary regulation energy, or in the event that the required conditions are verified, through of the deviant management mechanism.

6. Settlement of the process of resolution of technical restrictions. -This section describes in general the main aspects of the process of resolution of technical restrictions that have direct effect on the liquidation of this system tuning service.

The calculation of the receivables and the payment obligations arising from the process of settlement of restrictions is defined in the operating procedure whereby payment entitlements and payment obligations are established. by the system tuning services.

6.1 Liquidation of the provision of the technical restriction resolution service. The settlement of the provision of the technical restriction resolution service is established on the basis of the energy released and the prices incorporated in these redispatches, applied in the PDBF technical restrictions resolution process, in the intraday and in real time market, and in cases where applicable, in accordance with the energy measures.

6.1.1 Liquidation of energy programs. -Reoffices and prices incorporated in the same applicable to each of the units of sale and acquisition that have modified their program as a result of the processes of PDBF Technical Restrictions Resolution, Intradiary Market Technical Restrictions Resolution and Real-time Technical Restrictions Resolution, are specified in the Annex to this procedure.

6.1.2 Liquidation according to energy measures.-settlement with measures shall be applicable only to:

Power sales units for which, for system security reasons, their coupling and start-up, or an increase in their PDBF programme for the resolution of technical restrictions, have been scheduled identified in this programme (FASE 1), or for the resolution of the technical restrictions identified in real time.

Energy acquisition units on which the costs arising from the technical constraint resolution process are passed on.

6.2 Distribution of cost overruns resulting from the process of resolution of technical constraints. -Overruns of the PDBF technical restrictions resolution process and in real time will be calculated and passed on the criteria specified in the operating procedure for establishing the payment entitlements and the payment obligations for the system adjustment services.

7. Exceptional resolution mechanism. -In the event of emergency situations or for reasons of urgency, either because of the absence of offers due to force majeure or otherwise unanticipated or controllable, it is not possible to resolve the restrictions by means of the mechanisms provided for in this procedure, the OS may adopt the programming decisions it considers most appropriate, justifying its subsequent actions to the affected operators and the CNE, without prejudice to the economic settlement of the same as applicable in each case.

ANNEX I

Redispatches and pricing applicable to the provision of the technical constraint resolution service

1. Scheduled redispatches.

1.1 Technical restrictions resolution process of the daily operating base program (PDBF).

1.1.1 First phase: PDBF modifications by security criteria.

a) Sales units that increase the programmed energy in the PDBF for the resolution of technical constraints (Unit with Oblinked Program).

Energy redispatches scheduled for the resolution of technical restrictions of the PDBF will incorporate the prices of the simple offer presented by the corresponding unit of sale, except in the case of a a thermal group for which the holder of the unit has submitted a complex offer to the process of resolution of technical restrictions, and is applicable in accordance with the criteria set out in paragraph 3.3.3 of this procedure.

Scheduled units in the PDVP through a simple offer. -UPOPVPV-type power redispatches scheduled in the PDVP on power sales units for resolution of technical constraints will incorporate the price of each of the energy blocks of the simple offer used in whole or in part for the establishment of such redispatch.

Units programmed in the PDVP through a complex offer. -In those cases where the UPOPVPV redispatches are assigned to thermal groups that have submitted a complex offer and it is applicable according to the criteria laid down in paragraph 3.3.3 of this procedure, the energy redispatches shall incorporate the lower price between the following two:

a) The result of applying the complex offer to the program assigned in the PDVP by constraints.

b) The result of applying the complex offer to the final schedule of the unit after its participation in the different sessions of the intraday market and deducting from it the income associated with the valuation to the corresponding one the marginal price of your PDBF programme in descending loading ramp during the first three hours, and the net income (balance between income and payments) resulting from your participation in the various intra-day market sessions.

The calculations made for determining the price that will be incorporated in these redispatches will be applied in both cases on the set of periods that constitute the daily programming horizon, in addition to account, as appropriate, of cold or hot start of the production unit.

Programming with no offer existence for this process, or insufficient existing offering (UPOPVPMER). -In cases where the OS has to schedule the entry into operation or an increase of the program of a unit of Energy sales for the resolution of technical restrictions of the PDBF, by means of a redispatch of energy of type UOPPVPMER, not being affected the unit by an unavailability that prevents the realization of the program assigned for safety, and not existing offers submitted for that unit for the constraint resolution process technical, the energy redispatches programmed in each hour will incorporate a price equal to the result of applying a coefficient of majority KMAY, of value equal to 1.15, on the corresponding marginal price of the daily market.

b) Acquisition units and, where applicable, exports to external systems that reduce the programmed energy in the PDBF for the resolution of technical constraints (Unit with Oblinked Program).

UPO-type power redispatches scheduled in the PDVP, respectively, on energy acquisition units or, if applicable, exports, for the resolution of technical constraints, shall be considered equivalent to cancellations of the corresponding programme. Thus, depending on the type of transaction on which they are applied, they will result in the following program modifications:

Daily market transaction (UPOPVPB or UPOPVPE redispatch):

Reduction of the unit acquisition program in the same magnitude as the redispatch applied, incorporating a price equal to the corresponding marginal daily market rate.

Transaction associated with the execution of a bilateral contract with physical delivery (redispatch UPOPVPCBB or UPOPVPCBE):

Reduction of the energy program of the unit of sale and acquisition affects the bilateral contract, in the same magnitude as the redispatch applied, not incorporating this price.

c) Sales units that reduce the programmed energy in the PDBF for the resolution of technical constraints (Limited Program Unit).

UPL-type power redispatches scheduled in the PDVP on power sales units for the resolution of technical constraints, will be considered equivalent to cancellations of the corresponding program. Thus, depending on the type of transaction on which they are applied, they will incorporate the following prices:

Daily Market Transaction (UPLPVPV Redispatch):

Reduction of the energy program of the unit of sale at the same magnitude of the redispatch applied, incorporating this redispatch of program reduction a price equal to the corresponding marginal price of the market journal.

Transaction associated with the execution of a bilateral contract with physical delivery in which the acquisition unit corresponds to a national consumption (UPLPVPCBN redispatch):

Establishment in the PDVP of an energy acquisition program for the unit affects the bilateral contract, through the application on that unit of the corresponding redispatch, incorporating this a price equal to the corresponding marginal daily market time price.

Transaction associated with the execution of a bilateral contract with physical delivery in which the acquisition unit corresponds to a pumping consumption or, where appropriate, an export of energy to external systems (redispatch UPLPVPCB):

Reduction of the energy program of both the unit of sale and the acquisition unit affected to the bilateral contract at the same magnitude of the redispatch applied, not incorporating this price.

1.1.2 Second Phase: General Rebalance-Demand.

a) Sales units with programs associated with bilateral contracts with physical delivery whose demand has been reduced in Phase 1, and which reduce the programmed energy in the PDBF to obtain a balanced program in generation and demand.

ECOCBV energy redispatches scheduled in the PDVP on energy sales units corresponding to bilateral contracts whose demand has been reduced in the first phase of the resolution process technical restrictions of the PDBF, shall not incorporate any price.

(b) Acquisition units corresponding to a pumping consumption or an export through interconnections without a coordinated system of exchange capacity management with programmes associated with bilateral contracts with physical delivery the generation of which has been reduced in Phase I, and which reduces the programmed energy to obtain a balanced programme in generation and demand.

ECOCBV energy redispatches scheduled in the PDVP on energy acquisition units (pumping consumption or, where appropriate, export via international interconnections without a coordinated management system the exchange capacity) corresponding to bilateral contracts, the generation of which has been reduced in the first phase of the PDBF technical restrictions resolution process, shall not include any price.

c) Sales units that increase the programmed energy in the PDBF to obtain a balanced program in generation and demand, and pump consumption acquisition units that reduce the programmed energy in the PDBF with the same end.

Energy redispatches to be uploaded in the PDVP to solve a generation deficit and thus obtain a balanced generation-demand program, applied on a daily market transaction (ECO redispatch) or on an acquisition unit associated with a bilateral contract with physical delivery (ECOCB redispatch), shall incorporate the price of the corresponding block of the energy supply to be uploaded by that unit for the process of resolution of restrictions techniques and used in whole or in part for the establishment of such redispatch.

In the case of acquisition units that have not submitted the corresponding offer of energy to be raised for the process of resolution of technical restrictions, being however obliged to do so, the redispatch applied will pass to be referred to as ECOSSO redispatch, if associated with a market transaction, and ECOSCBSO redispatch, if it is associated with a bilateral contract with physical delivery, incorporating in both cases such redispatch a price equal to that resulting from applying a KMIN minoring coefficient, of equal value to 0.85, on the corresponding marginal price daily market time. For these purposes, a default price of the energy supply shall be considered to be raised for the resolution of technical restrictions of the corresponding unit of value equal to 85% of the corresponding marginal daily market time price.

d) Sales units that reduce the programmed energy in the PDBF to obtain a balanced program in generation and demand, and acquisition units that increase the programmed energy in the PDBF for the same purpose.

Power redispatches to be dropped programmed in the PDVP to resolve an excess generation and thus obtain a balanced program generation-demand, applied on a daily market transaction (ECO redispatch) or on a the unit of sale associated with a bilateral contract with physical delivery (ECOCB redispatch) shall incorporate the price of the corresponding block of the energy supply to be lowered submitted by that unit for the process of resolution of technical restrictions and used in whole or in part for the establishment of such redispatch.

In the case of sales units that have not submitted the corresponding offer of energy to be lowered for the process of resolution of technical restrictions, being however obliged to this, the redispatch applied will become referred to as ECOBSO, if it is associated with a market transaction, and the ECOBCBSO redispatch, if it is associated with a bilateral contract with physical delivery, incorporating in both cases a price equal to that resulting from the application of a KMAY, a value equal to 1.15, on the corresponding marginal price of the daily market. For these purposes, a default price of the energy supply to be lowered for the resolution of technical constraints of the corresponding unit of value equal to 115% of the corresponding marginal daily market time price shall be considered.

e) Redispatches applied to obtain a balanced program in generation and demand in the case of insufficient offers to run this process.

In cases where the OS has to schedule power redispatches to go up or down to solve a deficit or excess generation, respectively, and thus obtain a balanced program generation-demand, and once already the redispatches on all the units of both sale and acquisition that are obliged to the submission of offers, have not attended, however, this requirement, and also assigned all those offers presented for the process of resolution of technical restrictions, compatible with the respect of limitations applied for safety, and not yet sufficient allocation to restore the balance generation-demand, the redispatches which, if any, can be applied by the OS by MER, will bear the following prices:

Power Redispatch to Rise (ECOSMER Redispatch): Price equal to that resulting from applying a KMAY mayorance ratio equal to 1.15, on the corresponding marginal daily market time price.

Power Redispatch to Go Down (ECOBMER Redispatch): Price equal to the result of applying a KMIN minoron coefficient, of equal value to 0.85, on the corresponding marginal daily market time price.

1.2 Process of Resolution of Technical Restrictions on the Intradiary Market.-The redispatches applied for the withdrawal of offers of sale or purchase of energy from the intradiary market, for the resolution of the the technical restrictions identified in the programme resulting from such an appeal (RTIMO redispatch) or for the subsequent rebalancing of the generation-demand programmes (redispatch ECOMI), shall incorporate the corresponding marginal time-price Intraday market session.

1.3 Process of resolution of technical restrictions in real time. -Energy redispatches applied for the resolution of technical restrictions identified in real time will incorporate the price of the offers used to these effects: Tertiary regulation offers supplemented by the tenders submitted for the process of resolution of technical restrictions.

1.3.1 Redispatches applied by using the tertiary regulation offering.

1.3.1.1 Sales units that increase your energy program for the resolution of real-time technical constraints and acquisition units that reduce your energy program to the same end.

Power redispatches to upload of type UPOTRT scheduled in real time for the resolution of technical constraints, will incorporate the price of the tertiary regulation offer to be used for these purposes.

1.3.1.2 Sales units that reduce your energy program for the resolution of technical constraints in real time.

Power redispatches of type UPLTRT down scheduled in real time for the resolution of technical constraints, will incorporate the price of the tertiary regulation offer to be used for these purposes.

1.3.1.3 Pump consumption acquisition units that increase your energy program for real-time technical constraint resolution.

The increase of the pump consumption program of a procurement unit for the resolution of technical constraints in real time will be associated with a power redispatch to drop of type UPLTRT. This redispatch shall have an energy equal to the magnitude of the increase in the programme, incorporating a price equal to the sum of the price of the tertiary regulation offer to be used for these purposes, and of the result of applying a KBO coefficient, of a value of 0,70, on the corresponding marginal daily market price.

1.3.2 Redispatches applied by using the submitted offer for the technical constraint resolution process.

1.3.2.1 Sales units that increase your energy program for the resolution of real-time technical constraints and acquisition units that reduce your energy program to the same end.

Power redispatches to upload of type UPOTROR scheduled in real time for resolution of technical constraints, will bear associated the price of the offer of energy to be uploaded for that unit to the process of resolution of technical restrictions and used for these purposes.

1.3.2.2 Sales units that reduce your energy program for real-time technical constraint resolution.

Power redispatches of type UPLTROR to be scheduled in real time for the resolution of technical constraints, will be associated with the price of the offer of energy to be lowered presented for this unit to the process of resolution of technical restrictions and used for these purposes.

1.3.2.3 Pump consumption acquisition units that increase your energy program for real-time technical constraint resolution.

The increase of the pump consumption program of a procurement unit for the resolution of technical constraints in real time will be associated with a power redispatch to be lowered of type UPLTROR. This redispatch will have an energy equal to the magnitude of the increase in program, incorporating a price equal to the sum of the price of the offer of energy to be lowered presented for that unit to the process of resolution of technical constraints and used for these purposes, and for the result of applying a KBO coefficient of 0,70 on the corresponding marginal daily market time price.

1.3.3 Real-time applied redispatches not covered with tertiary regulation offerings or offers submitted for the technical constraint resolution process. -In cases where the OS has to schedule redispatches of energy to be raised or lowered for the resolution of technical restrictions identified in real time, without any offers of tertiary regulation, or offers submitted for the process of resolution of technical restrictions, or These are insufficient to cover fully the redispatches applied by the security in real time, the redispatches which, if any, can be applied by the OS by MER, will bear the following prices:

Power Redispatch to Rise (UPPER type): Price equal to the resulting from applying a KMAY shift coefficient, equal to 1.15, over the corresponding daily market time marginal price.

Power Redispatches to Go Down (UPLMER type): Price equal to that resulting from applying a KMIN minoron coefficient, of equal value to 0.85, on the corresponding daily market time marginal price.

In the case of pump consumption acquisition units, the increase of your program for the resolution of technical constraints in real time will bring two energy redispatches to be reduced of type UPLMER. These redispatches will each have an energy equal to the magnitude of the increment of the program, incorporating one of them a price equal to the result of applying a coefficient of minoría KMIN, of value equal to 0.85, on the corresponding price marginal daily market time, and the other a price equal to that resulting from the application of a KBO coefficient, of 0,70, on the corresponding marginal daily market price.

2. Effective implementation of the redispatches scheduled in accordance with measures. -The OS shall determine in accordance with the measures, in those cases where applicable, the modifications that are necessary for the prices incorporated in the scheduled redispatches, taking into account the planned starts and the specific type of start-up (cold or hot) scheduled, and the fact that they have been effectively produced in accordance with the measures received, as well as the actual energy measured for the unit and the energy for it programmed by security criteria (Phase 1).

In the event that the energy measured in an hour for a unit of sale is lower than the security programmed, the unfulfilled energy shall be valued at the price resulting from the difference between the weighted average price of the whole energy programmed to rise for the resolution of technical constraints and the corresponding marginal daily market time price.

P. O. 9. Information exchanged by the system operator

1. The purpose of this procedure is to define the information to be exchanged by the System Operator (OS) in order to perform the tasks entrusted to it, as well as the form and time limits for which it must communicate or publish it.

This information includes, inter alia, the information on the structural data of the installations of the electrical system, the data relating to the real time situation of the electrical system (state, measures, etc.), the information exchanged for the proper operation of the system, the information necessary for the compilation of the statistics relating to the operation of the system, the information required for the analysis of the effects of the electrical system, as well as the information referred to to the data for the settlement of the transactions carried out on the production market of electrical power.

It is established in this Procedure, with the detail that comes in each case, the way in which the exchange of information between the OS and the different subjects of the Spanish electrical system will be carried out, the way of access to the information, how to structure and organise it (databases), its character (public or confidential) and its subsequent treatment (analysis, statistics and reports).

2. Scope. -Within the scope of the Peninsular Electrical System:

System Operator (OS).

Market Operator (OM).

Distribution network managers.

Carriers.

Market subjects and other system subjects defined in the electrical sector regulation.

3. Information management processes in which the system operator intervenes. -Information exchange processes in which the OS is involved can be grouped as follows:

a) Structural Data of the Electrical System.

b) SIOS: System Operation Information System.

c) Main Electrical Measurement Concentrator.

d) SCO: Real Time Operation Control System.

e) Other information to be sent by system subjects.

f) Statistics and Public Information regarding the System Operation.

g) Analysis and incident information in the electrical system.

h) Liquidation under System Operator responsibility.

As far as the headings b, c, d e and f are concerned, the system subjects shall be responsible for depositing in the OS information systems the information contained in this Procedure, as well as for providing the information. necessary communication mechanisms and take charge of their costs.

The subjects will ensure that:

a) The information provided is correct.

b) The information is available to the OS with the minimum time delay and with the appropriate time stamp.

c) Communications systems are redundant, reliable, and secure.

d) The transmission of information conforms to the characteristics of communication protocols and frequency of sending information defined by the System Operator.

4. Structural data of the electrical system. -It is the data of the installations of the transport network and the observable network, as well as of the generating groups, consumers and elements of control, that the OS requires to exercise its functions the safety analysis and the performance studies of the electrical system.

4.1 Responsibilities. -The OS is responsible for collecting, maintaining, and updating the electrical system's structural data. The information is structured and organized in the Structural Data Base of the Electrical System (BDE).

The subject holders or representatives of programming units for the sale of energy in the production market, consumers connected to the transport network, the carriers, the distributors, the managers of the distribution networks, they shall be obliged to supply the OS with the necessary information of the elements of their ownership or to those they represent in order to maintain the content of the updated and reliable BDE.

4.2 Content and structure of the Database. -The BDE will include the records of all the items discharged into the electrical system managed by the System Operator. It shall also include the records of elements in project and construction and of planned elements, with the available values, although these shall be considered provisional until they are put into service. These last records will be released to facilitate the conduct of the transport network planning studies and the different forecasts analysis of the electrical system.

The contents of the BDE will respond to the following structure:

Production System:

Reservoirs.

Common system and hydraulic groups.

Ordinary-speed thermal units.

Special regime units.

Transport Network:

Substations.

Parks.

Lines and cables.

Transformers.

Active or reactive power control elements.

Consumer installations connected to the Transport Network.

Observable Network:

Substations.

Parks.

Lines and cables.

Transformers.

reactive power control elements.

A detailed relationship of the different fields in which the BDE is structured is included in Annex 1.

4.3 Load processing. -The OS will define the computer support used and enable the templates of the data entry tabs with the required formats.

The OS will complete the fields contained in the above sheets with all the information available to them about each item and make them available to the owner or representative of the item to which the information.

The subjects will carry out a check of the information of the files relating to their installations and modify them, if appropriate, with the best information available, filling in the fields that appear empty.

Once the tokens are completed and validated by each subject, the subject will communicate the outcome of the review to the OS.

4.4 Update of information.-The update of the information contained in the BDE may be facilitated by any of the following three circumstances:

For design modifications to some element.

By high or low of some element.

Because a bad value has been detected in some field.

When any of the above three circumstances occur, the subject who owns the corresponding item or the subject acting in its representation shall communicate to the OS the necessary modifications to be incorporated.

The OS will periodically make available to each subject the data of the elements of their property or those to whom it represents collected in the database in order to enable the subjects to check their proper correspondence with the actual data of the installations and, where appropriate, communicate to the OS the necessary modifications to be made.

4.5 Confidentiality of information.-The information contained in the BDE will be confidential for all subjects except for:

The NEC, which will be able to have all the information.

The competent energy administration, which will be able to have all the information.

The distribution network managers, who will be able to have the data from the facilities located in the distribution network under their management scope.

Those third parties to whom the OS has the need to give information for the exercise of its functions and obligations, minimizing, in any case, the volume of information transmitted.

All Subjects who may have the data relating to the facilities in service of the transport network.

5. Information systems of the system operator. -Data that, in the performance of its functions, the OS must manage to perform the processes it has entrusted, from the communication of the bilateral contracts established with prior to the daily market, the appeal of the tenders submitted to the market on the daily and intraday horizon, bilateral contracts with physical delivery communicated to the OS after the daily market and programmes on the interconnections international, including, the processes associated with the allocation of capacity in those interconnections, until the establishment of each of the time schedules and the allocation of the system adjustment services, will be managed by the System Operator Information Systems (SIOS).

The e-sios Information System will perform the processes, auction, calculation, recording and file of intermediate data and results of the processes indicated above.

The e-Sica Information System will perform explicit auctions for capacity allocation in those international interconnections in which this process is applicable.

The SIOSbi Information System will perform the file, management, and publishing of the historical information associated with the previous processes.

Information managed and stored by the System Operator Information Systems will also be used later in the settlement processes that are the responsibility of the OS.

SIOS constitutes the only means of the OS for the realization of the exchange of information with the subjects of the market of electrical energy production (SM), the OM and other subjects of the electrical system.

In the execution of the processes and exchanges of information indicated in the preceding paragraph, the SIOS shall ensure:

a) Absolute confidentiality and all evidence of information owned by each market subject (SM).

b) Receipt of receipt to each market subject of their offers, with timestamp.

c) Remote, fast, reliable and easily usable access system.

In order to ensure maximum availability, SIOS Information Systems are redundant systems. In addition, the e-sios has a backup system in a different location of the main system. The OS will inform users of the access modes to both systems.

With a periodicity to be established by the OS, the processes performed by the e-sios will be executed in the backup center, being the responsibility of subjects of the market for the production of electrical energy (SM), the OM and other subjects of the The power system will have the media with this backup center using the access modes defined by the System Operator.

5.1 Databases of the system operator information systems. -The OS will maintain in its databases all the information necessary for the correct management of the operation programming, the adjustment services of the system and the management of international exchanges that are under your responsibility.

The SIOS databases will meet the following requirements:

a) Dimensioning appropriate to allow the storage of all information.

b) All the information in the databases will be validated.

c) The referential integrity of the recorded data.

d) Historical management associated with all information.

5.2 Access to the SIOS.-Access to the SIOS by the market subjects, the OM, other subjects of the electrical system or the general public, will be done according to the character of the information to which you have access, either public or confidential in accordance with the criteria set out in paragraph 5.3.

5.3 Media exchange of information. -Communication between the OS, the OM and the Market Subjects and other participants or entities participating in the production market, as well as the disclosure of free public information access shall be made by electronic means of exchange of information, using at any time the technologies which, in accordance with the requirements set out in paragraph 5, are more appropriate.

The adoption of new electronic means of exchange of information, as well as the suspension of the use of any of the existing ones, will be communicated to the users in good time in such a way that they can carry out appropriate modifications to their information systems.

The OS will publish the electronic means of exchange of information available and its characteristics, those new ones that will be implemented and those that will be suspended, as well as the deadlines foreseen for this.

5.4 Communications. -For the realization of information exchanges, the OS will have several alternative means of common use to access both the main and the backup system and will communicate to the users the Technical details required for access and performance procedures in case of switching between the two systems.

The installation, maintenance and configuration of the communication channels to access the SIOS will be the responsibility and will be borne by the users, except bilateral express agreement. The OS shall indicate in each case the rules and procedures applicable to the equipment to be installed on its premises.

5.5 Access Services. -According to the type of information, there will be two access services: private and public.

Private service will be reserved only for market subjects, OM and other electrical system subjects.

The electronic addresses of the public and private access services will be provided by the System Operator.

Access services, both private and public, will use the most appropriate technologies in each case.

For the use of the private access service, a personal authorization granted by the OS will be necessary according to the regulations in force. No authorization type will be required for the use of the public access service.

5.5.1 Private access service security. -At present, the private access service security system is based on the use of the following elements:

a) The encrypted communication channel to ensure the privacy of the information exchanged.

b) Use of digital certificates for authentication when making connections to SIOS, the signature of electronic documents constituting information exchanges and ensuring the non-repudiation of such documents.

c) Use of smart cards. For the same purpose as the certificates in paragraph (b) above, the SM and other production market entities and subjects may own one or more smart cards, where their digital certificate is stored, as well as their data identification and code to prevent misuse in case of theft or loss. The depositaries of these cards will be responsible for the management of this code, being able to modify it when they create it convenient. Likewise, in case of theft or loss, they must communicate this fact as soon as possible to the OS, in order for the OS to discharge the associated certificates.

Digital certificates will be issued by the OS acting as a Certificate Authority. Users recognize the OS as a trusted Certificate Authority for the sake of using the digital certificate or smart card.

Digital certificates will be issued with an expiration date. It shall be the responsibility of the user of the certificate to check that expiry date and to request, where appropriate, the renewal of the certificate in advance not less than 5 working days from the expiry date.

Also, it will be the responsibility of the SM or market entity to request the cancellation of the certificates when they consider it convenient (for example, cessation of activity of users responsible for the certificates).

5.6 Information Management.-The OS will be able to establish with the outside information exchanges in both directions:

Information communicated by the OS.

Information communicated to the OS.

The information exchanged by the OS may have different characters:

Public.

Confidential in terms of paragraph 5.3.4.

5.7 Information exchanges. -All exchanges of information will be carried out by electronic documents of certain content and format, which will be published by the OS in the SIOS or communicated to the SIOS by the SM, OM and other participants or entities participating in the Spanish production market, by the means to be established, in the schedules specified in the corresponding Operation Procedures.

Electronic documents exchanged with the Market Subjects and other subjects and entities in the electrical market, their content, format and time limits for publication or receipt by the OS are described in a single document "Information Exchange with the System Operator", organized in a series of volumes:

Volume 1. Production Markets.

Volume 2. Liquidations.

Volume 3. Tension Control.

These volumes and their modifications will be published, in good time before their entry into force, on the public website www.esios.ree.es of the System Operator Information System.

Electronic documents exchanged with participants in capacity allocation processes in interconnections through explicit auctions will be published in the e-music system: www.esica.eu.

The documents exchanged with the Market Operator its content, format and time limits for publication or receipt by the OS are described in the document called " Model of Ficheros for the Exchange of Information between the OS and the OM " to be published jointly by the OS and the OM by the means that each operator establishes.

5.8 Information Advertising Criteria. -The criteria for advertising the information managed by the OS on the processes related to the Electricity Production Market are those established in the Royal Decree-Law. 6/2000, of 23 June, in the CNE's 1/2001 report on the proposals for amendments to the Rules of Procedure of the Market with the aim of adapting them to the Royal Decree-Law 6/2000, in the Rules of Operation of the Market approved by Resolution of the Secretariat of State for Economic Affairs, Energy and Small and Medium-sized Enterprises, dated 5 June April 2001, published in the B.O.E. dated April 20, 2001, and in the General Directorate of Energy Policy and Mines dated November 19, 2004.

These criteria are as follows:

The OS will make public the result of the processes of operation of the electrical system, being these objects of its responsibility.

The OS, in the field of its competence, will make public the comprehensive aggregated data of volumes and prices, as well as the data relating to the commercial capabilities, intra-Community and international exchanges interconnection and, where applicable, by electrical system, as well as the corresponding aggregate supply and demand curves.

All information that the OS provides to a subject on another, and which does not come from a claim, must be provided to the general public.

In any event, the OS shall ensure the confidentiality of information of a confidential nature made available by market subjects, as provided for in paragraphs 2f) and 2k) of Articles 27 and 30 respectively of the RD 2019/1997.

5.9 Public Information-Information that the OS makes public about the operation processes of the electrical system.

This information depends on the period to which the information is affected and the time it is made public.

5.9.1 In real time. The information that the OS will release as soon as it becomes available is as follows:

The forecast of the demand of the Spanish peninsular system with a horizon of 30 hours.

The forecast of the wind production of the Spanish peninsular system with a time horizon between the hour following that publication and the final time period of the next day.

The ability to exchange updated international interconnections in real time.

Real-time, real-time international exchange aggregates and programs.

The aggregate result of the solution of real-time technical constraints and the communication of other annotations (inavailabilities and deviations) performed during the real-time operation.

The aggregate result and marginal price of the markets for the adjustment services of the tertiary regulation system and the management of deviations.

Unbundled Operational Schedules (P48) programs that result after all allocations made to real time are incorporated into the program.

5.9.2 Daily. The following information will be published on a daily basis:

The aggregated specifications and results of the daily and intra-day explicit coordinated auctions of interconnection capacity with France, in the form and time limits laid down in the operation procedure relating to the resolution of congestion in the France-Spain interconnection.

At a time of not less than one hour before the closing time of the period for the submission of offers to the daily market, the following day information for:

Capacity to exchange international interconnections.

Demand for Spanish peninsular system demand.

The forecast of the wind production of the Spanish peninsular system.

After the corresponding market or technical management process:

The aggregate output of the swap capacity auction between physical bilateral contracts for those interconnections where there is no coordinated capacity allocation mechanism.

Aggregated results of the solution of supply and technical guarantee restrictions in the PDBF and after each of the intraday market sessions.

Aggregate result and marginal price of the secondary throttling power reserve allocation.

Added result of the daily allocation of additional resource offerings for the transport network voltage control.

Day D + 1 the information for day D:

Aggregate result and marginal price of secondary regulation energy.

5.9.3 At three days. -After three days from day D of programming, the information broken down by type of technology, or if applicable, by type of subject, will be published.

The information to be published on day D + 4 corresponding to the result of the time schedule of day D operation markets will be broken down by the following types:

Nuclear.

Carbon.

Fuel-Gas.

Combined cycle.

Conventional hydraulics.

Pumping turbination.

Consumption pumped.

Energy imports and exports.

Special regime participating in the production market.

Market participant special regime production by means of the regulated rate remuneration option.

Last Resource Marketer (CUR) acquisitions corresponding to the national last resort supply.

Acquisitions of marketers destined for domestic consumption in the free market.

Direct consumers on the market.

Auxiliary services of production units.

Generic Programming Units.

5.9.4 Weekly. -The OS will publish on its website the power of electrical generation available in ordinary system aggregated by generation technologies (nuclear, coal, hydraulic, fuel oil, combined cycles).

Before 6 p.m. every Thursday, the capacity of exchange with each of the interconnected electrical systems interconnected for each programming period of the following two electric weeks, beginning at 00.00h of the Next immediate Saturday.

5.9.5 Monthly.-On a monthly basis, the demand forecasts for full months will be published, in the first 15 days of the month preceding the one referred to in the forecast.

The OS will publish the aggregated specifications and results of the monthly explicit coordinated auctions of capacity for interconnections with France and Portugal, in the form and deadlines set out in the Operation relating to the resolution of congestion on the France-Spain and Portugal-Spain interconnections, respectively.

The OS will publish on its website the power of electrical generation available under ordinary system aggregated by generation technologies (nuclear, coal, hydraulics, fuel oil, combined cycles).

Also, monthly payments will be published monthly per subject obtained as a result of the system's markets or operating processes.

The first day of the month M + 2 will be published the quotas per subject in month M on the following markets or system operation processes:

Solution of supply and technical warranty restrictions, respectively, in the Base Operating Program (PBF).

Solution of technical constraints on the intraday market.

Real-time technical constraint solution.

Managing deviations between generation and consumption.

Secondary throttling power reserve.

Energy used for secondary regulation.

Tertiary Regulatory Energy.

Additional resources allocated for reactive power.

Reactive energy.

5.9.6 Quarterly. -The OS will publish on its website the power of electric generation available in ordinary system aggregated by generation technologies (nuclear, coal, hydraulic, fuel oil, combined cycles).

The specifications and aggregated results of the quarterly explicit coordinated auctions of capacity for interconnection with Portugal, in the form and time limit laid down in the operation procedure for the resolution of congestion at the Portugal-Spain interconnection.

5.9.7 At three months. -After three months from the day it relates, the confidential information contained in paragraph 5.3.4 that is communicated to each market subject (SM), including the offers, will be published. submitted by the SM to the system tuning services.

5.9.8 Annually. -The following information will be published:

Before 30 November of each year, the expected capacity levels for the following year for each of the interconnections and flow senses.

The aggregated specifications and results of the annual explicit coordinated auction capacity of the interconnections with France and Portugal, in the form and deadlines set out in the related operating procedures to the resolution of congestions in the France-Spain and Portugal-Spain interconnections, respectively.

The power of electrical generation available under ordinary system aggregated by generation technologies (nuclear, coal, hydraulics, fuel oil, combined cycles).

5.10 Confidential information. -Confidential information is the one that communicates to the subjects of the system individually without access to it by the other subjects, up to once after three months from the timing of their communication in a confidential manner, in accordance with the previous paragraph.

This information refers to the programming processes of the operation of the system, to the system adjustment services and to the information regarding the international exchange programs, processes all established in the Operation Procedures:

International exchange programs.

Solution of supply warranty restrictions (redispatches).

Solution of technical constraints (limitations and redispatches).

Managing deviations between generation and consumption.

Secondary secondary regulation service.

Complementary tertiary regulation service.

Supplemental transport network voltage control service.

Other annotations made during real-time operation (inavailabilities, statements, etc.).

The communication criteria to be adopted according to the subjects or participating in the operating markets are as follows.

5.10.1 to the Market Operator (OM). -You will be notified of all necessary information for the proper management of the daily and intraday market and that other additional in compliance with the provisions of the current legal regulations.

5.10.2 To market subjects.-The detailed information for the units of their property, or those they represent, will be communicated to them.

To owners of shared production units that are not however responsible for sending bids on the operating markets will be communicated the information of the outcome of the operating markets but not the information on the related offers associated with these markets shall be communicated to them.

To the owners of units affected by international physical bilateral contracts that are not, however, responsible for the communication of offers for the auctions of capacity to exchange those interconnections in Those that do not yet have a coordinated capacity allocation mechanism shall be communicated only to the outcome information of the technical restriction solution process on those interconnections.

The participants of explicit exchange capacity auctions will communicate the detailed information corresponding to the outcome of their bids.

Weekly, to owners or representatives of programming units associated with plants using autochthonous coal as fuel included in Annex II to Royal Decree 134/2010, of 12 February, and in the regulations The OS shall communicate the information corresponding to the operating plan for the following immediate electrical week (including 0.00 hours each Saturday and 24:00 p.m.). the following immediate Friday hours), according to the procedure of operation by which provides for the resolution of restrictions by security of supply. On a daily basis, the OS will make available to each SM, the possible updates of its weekly operating plan that need to be considered a function. the evolution of the forecast demand, the forecast of production of renewable origin and/or the over-sold inavailabilities affecting production units and/or network elements.

The OS daily will make available to each of the plants involved in the process of resolution of restrictions by guarantee of supply, the maximum volume of production that can be programmed as the difference between the maximum production volume fixed for each plant annually by Resolution of the Secretary of State for Energy and the energy actually produced in each of the plants from the first day of the corresponding year.

The OS shall make available to the market subjects holding of production units connected to the transport network the expected situation of the transport network, which shall include scheduled and fortuitous inavailabilities.

The OS will also make PSS/E (software for the analysis of electrical power systems) used for the analysis of technical restrictions of the Operational Base Program available to market participants. (PBF) before three working days from the date of the scheduling day.

5.10.3 To other subjects or entities participating in the operation programming process.

5.10.3.1 aggregating entity of the Energy Primary Emission Auction (EASEP). -The OS will communicate to EASEP the updated information for Market Subjects in the production market and Programming Units. Generic requirements for participation in the Primary Emission Auction, when the exercise of the purchase options is for physical delivery.

Monthly, EASEP shall communicate to the OS the relationship of the SM holders of primary emission purchase options, arising from the award in such auctions and the possible bilateral transfers of such options and the maximum power value associated with each SM partner-SM seller, when the exercise of the options is by physical delivery.

On a daily basis, the OS will receive from EASEP the nomination of bilateral CBEP contracts associated with the exercise of the energy purchase options after the primary energy auctions, when the exercise of the options is by physical delivery.

5.10.3.2 To the distribution system operators. -They will be notified of the information of the registered net power generation facilities of more than 50 MW and of the network facilities corresponding to the network under their management and the network observable by themselves. The generation information will be broken down per unit and will include the inavailabilities of groups. Information on the status of the network shall include the inavailabilities both programmed and fortuitous.

They shall also be provided with the information corresponding to the programming units that integrate the generation of production facilities with a registered net power of less than or equal to 50 MW in the production market. as the associated inavailabilities, if applicable.

The OS, in case it considers necessary the inclusion of information that does not correspond to the own area of the manager of a distribution network, will present to the National Energy Commission for approval its proposal of network observable for this manager, including the explanatory statement for which the inclusion of this additional information is deemed necessary.

The OS, on a monthly basis, will make it easier for the distribution system operators to whom the transitional provision of Law 54/97 does not apply to them, the information concerning the subscription to the control centres of the facilities registered in such centres.

5.11 Exchange of measurement data. -Information that is exchanged between the Main Electrical Measurement Concentrator and the OS SIOS.

5.12 Structural Information Management. -For the proper functioning of the services and processes managed by the OS it is necessary to know and maintain information regarding the Market Subjects (SM), Programming Units (UP), Offer Units (UO) and Physical (UF), Bilateral Contracts, as well as a number of additional data and technical parameters required for the programming of the system operation. All this information is collected under the Structural Data name.

The treated data will be grouped as follows:

Market Subject Information: data of the subjects on the market and, where appropriate, of subjects acting on behalf of others.

Information on Programming Units and their relationship to the Offering Units used in the daily and intraday markets (including Generic Programming Units).

Information about programming units and their unbundling in physical units and equivalent physical units.

Different character information: market types, drive types, security cards.

Various types of parameters, which affect the system.

Information about the different sessions that make up and define the different Markets managed by the System Operator.

5.13 Display of structural information. -Using the Web page of E-sios Market Subjects: https://sujetos.esios.ree.es, the SM will be able to access the confidential structural information corresponding to:

Programming Units (including Generic Programming Units) of your property or those that represent on the production market.

Physical units of your property or those that you represent in the production market.

Bilateral contracts involving the Programming Units of your property or those representing them on the production market.

Tension Control Service Delivery Units.

Also, through the e-sys public website: http://www.esios.ree.es, the SM will have access to the non-confidential structural information of other SM, corresponding to Programming Units, Physical Units, Regulation and Market Subjects of the Spanish electricity system.

5.14 Request for modification of structural information.-The modification of the structural information will be requested by sending to the OS of the corresponding form available on the web page of SM duly completed by the SM and accompanied by documentary support supporting the change.

Once the modification requested by the SM has been revised, the OS will communicate to the SM the date for which the requested change will be made, or, if necessary, the reason for the failure to do so.

6. Main Hub of Electrical Measures. -Main Concentrator of Electrical Measures is the system with which the OS manages the information of measures of the Spanish electrical system according to the requirements laid down in the legal regulations in effect.

6.1 Content of the Main Electrical Measurement Concentrator database. The Main Hub database collects the data necessary for the management of the measurement system and will be at least the following:

a) The structural information resident in the Main Hub for borders of which the OS is in charge of reading:

Measurement Points.

Border points.

Measure point relationships with border points.

Counters.

Registrars.

Measure transformers.

b) The information of measures resident in the Main Hub for borders of which the OS is in charge of reading:

Time measures on measurement points.

Hourly data for measures calculated at the border points.

Hourly data for measures calculated in the Programming Units.

c) The structural information resident in the Main Hub for borders of which the OS is not in charge of reading:

Client points types 1 and 2 (CUPS).

Customer measure point and special regimen types 3, 4, and 5.

d) The information of measures resident in the Main Hub for borders of which the OS is not in charge of the reading:

Hourly measures in customer CUPS types 1 and 2.

Hourly data for aggregate customer and special regime measures.

e) Additionally will have other information that will include at least:

Hourly data for measures calculated in the Programming Units.

Transport network losses.

Accumulated between activities.

Consumer profiles.

6.2 Access to the Information from the Main Hub of Measures. -The OS manages access to the resident measures information on the Main Hub as indicated below.

6.3 Free Access Information-The OS publishes a variety of general reports from the energy and inventory data available at the Main Hub.

This information is available from the Internet address of the OS (http://www.ree.es).

6.4 Information for the participants of the measurement system. The information contained in the Main Concentrator of Electrical Measures is of a restricted nature, so that only each participant in the measurement system You can access data from the border points and/or aggregations from which you are involved.

The OS has developed a secure access system, whereby each participant in the measurement system will be able to consult at least the following information on the Main Electrical Measurements Hub:

Time measures of the measurement points for which the OS is in charge of reading.

Time measures of the border points on which the OS is responsible for reading.

Setting up the border points of which the OS is in charge of reading.

Inventory of the measurement points from which the OS is in charge of reading.

Time measures in CUPS types 1 and 2.

Aggregations time measures types 3, 4, and 5.

The OS Internet address indicates the requirements and procedure to be followed for the use of such secure access to the Main Electrical Measurement Concentrator.

Additional and regardless of the secure access described above, the OS will publish and exchange measure information with the secondary hubs according to the protocol defined in the Operation Procedure P.O. -10.4 and users of the Main Hub. The content and format of the different measures data exchanged by the participants of the measurement system will be the latest version of the document 'Ficheros for the Exchange of Measures Information'. The wording of this document is the responsibility of the OS and will be available on its website.

6.5 Information Management.-The Main Hub receives and manages the information exchanged between the border points of the Spanish electrical system in accordance with the requirements laid down in the legal regulations in effect.

6.6 High of border points, aggregations and other structural data. -The high, low and/or modification of borders and aggregations along with the rest of structural data will be carried out according to the legislation in force the development documents "Ficheros for the exchange of Measures Information" and "Information for holders of special regime installations" published on the System Operator's website.

6.7 Main Concentrator Measures Reception.-Sending measurement data to the main hub will be done according to the means, protocols, and deadlines set forth in the current legislation.

6.8 Other considerations on the information of measures. -Information on electrical measures will be available at the Main Hub for a minimum period of six calendar years, counted from the following year the date of each measure. Access to information more than two years old may require a special procedure.

7. SCO (REAL-TIME OPERATION control system).-The OS will need to receive all information from the transport and production facilities, including the generation in the real time, in its Operation Control System in real time. special arrangements and the observable network-as defined by the latter in the procedure of operation P.O. 8.1 defining the networks operated and observed by the OS-which is required to operate in the electrical system. To do this, the OS will have the corresponding Operation Control System Database (BDCO).

7.1 Production facility control center. -Real time information regarding production facilities of net power equal to or greater than 10 MW (or in aggregate form of those power plants which are part of a set whose connection is made to the same knot of the voltage grid equal to or greater than 10 kV and add up to more than 10 MW) shall be captured by means of its own and provided to the OS through connection between its centres of control.

Those units of production of power greater than 1 MW that do not meet the conditions set out in the previous paragraph, have no obligation to be integrated into a control centre, but must send the telemetry of their real-time net production to the OS through the area's distributor control center.

In the event that the production facility is integrated into a regulatory area, its control center will be the generation dispatch of the owner of that regulatory zone.

7.2 Content and structure of the SCO Database (BDCO).-The information given below will be received in the SCO Database and with the technical specifications that are also reflected.

7.3 Technical Requirements. The information to be exchanged with the OS will be performed according to a standard communication protocol to be determined by the OS. The frequency of the information to be exchanged for secondary regulation data shall be equal to or less than the master regulator cycle. The rest of the information will be exchanged with a periodicity to be determined by the OS with each market subject, which in no case will exceed 12 seconds.

The OS will maintain the confidentiality of the information received. However, it may send to market subjects such information as they request, provided that such information is necessary to ensure the development of their functions as regards the operation of the market. system (voltage control, safeguard plans, emergency and replacement of the service) and the authorisation of the holder of the information generated.

7.4 Required Information. -Information will be required for the facilities listed below:

Transport Network.

Observable network.

Level of filling of reservoirs in pumping stations.

7.4.1 Definition and general criteria for standard collection of signals and measurements. -In this procedure, the set of elements associated with line, transformer, reactance, bars or coupling of bars that are accurate for maneuver and operation.

The (open/closed) state of the switches and dryers will be given by 2 bits. The rest of the signals will be given with one.

Given their uniqueness, the Synchronous and Condenser Compensators have been separately considered.

The following considerations have been taken into account in the way the signals are captured:

(a) Under the heading of transformers, they are considered even those of groups and consumption.

b) The following classification of the information has been performed to fetch:

1. Signs. -Includes states (open/closed) or indications of devices that do not constitute anomalies or states of malfunction. Included here are the topological states of the network (open/closed states of switches and dryers).

2. Measures. -Includes analogue or digital measures for discrete numerical magnitudes of the installation (e.g. indication of transformer sockets).

The detailed information for the signals to be captured is given in Annex 2.

8. Other information that subjects must send to the System Operator. -The OS will be responsible for collecting all other information regarding the operation of the system described in this section.

It is the responsibility of the producers, carriers and managers of the distribution networks to provide the OS with the information required by it and to derive from the operation of the facilities of their property or under the scope of their management.

In addition, the distribution system operators shall collect from the generators in particular their scope, the information necessary for the operation and send it to the OS with the frequency specified.

In case of not being able to dispose of some of this data, they will cause to the OS their best estimate of them.

The following data will be sent to the OS with two different levels of temporary aggregation (daily and monthly), necessary to maintain the statistical series related to the energy balance sheets and the operation system, as well as to perform security coverage and analysis forecasting.

8.1 Daily data.-The system subjects will provide the OS with all the data necessary for the elaboration of the official statistics, using the established information exchange channels. All values of the magnitudes listed below shall be given with the greatest disaggregation possible in physical units. The maximum time limit for the submission of such data shall be the following four working days:

Daily production forecasts with hourly breakdown and by technologies of all facilities of special regime at tariff that choose to cede the electricity to the distribution company and are connected to the transport network, in accordance with the provisions of the Sixth Transitional Provision of R. D. 661/2007.

Production of thermal groups on alternator bars (b.a.).

Production of hydraulic power plants with installed power equal to or greater than 10 MW, in central bars (b.c.).

Hydropower production by hydraulic subsystems.

Maximum hydroelectric power that can be maintained by each hydraulic supply unit for four consecutive hours.

Production of wind farms with installed power equal to or greater than 10 MW.

We consume your own generation.

Consumption of pumping stations.

Accumulated energy available for generation in pumping stations.

Fuel consumption in thermal power plants.

Fuel stocks in thermal power plants.

Hydrological information:

Precipitation.

Means of rivers in aphorous stations.

Hydroelectric reserves by reservoirs (in hm3 and MWh).

Spills.

Incidents on the Transport Network.

8.2 Monthly data. -The following monthly data will be sent to the OS before the 20th of the following month with the maximum level of disaggregation possible in physical units:

Production of thermal, gross and net groups.

Hydroelectric production (gross and net) by hydraulic subsystems.

Production of hydraulic power plants with installed power equal to or greater than 5 MW, in alternator borns and reserves in the associated reservoirs.

turbable losses in hydraulic power stations with installed power equal to or greater than 5 MW.

We consume your own generation.

Consumption and production of pumping stations.

Accumulated energy available for generation in pumping stations.

Hydroelectric reserves by reservoirs in hm3 and MWh.

Energy produced at the rate of the Special Regime.

Energy produced by each producer with the Special Regime.

Consumers of each producer's own consumption and consumption under the special scheme.

Fuel input in power plants/thermal groups (in tonnes and termine (PCI)) broken down by coal or fuel oil classes at the power plants of this type.

Fuel consumption in central/thermal groups (in tonnes and termine (PCI)) broken down by coal or fuel oil classes at the plants of this type.

Fuel stocks in power plants/thermal groups (in tonnes and termine (PCI)) broken down by coal or fuel oil classes at the plants of this type.

Lower heat power of each of the fuels used in the generation.

Planned plan for reduced deliveries of guaranteed coal for the next twelve months (expressed in tonnes and in termine (PCI) and quantities of the year in progress actually delivered to date.

Foreseeable variations in the availability of production groups (thermal, hydraulic and pumping), as indicated in the procedure for establishing the maintenance plans of the production units production.

9. Statistics and public information regarding the operation of the system. -The OS will publish the data that is later indicated on the operation performed, including the behavior of the transport network and the means of generation.

9.1 Daily information. The information that the OS will publish daily is as follows:

System load curve.

State of hydroelectric reserves and contributions in the most important rivers.

9.2 Information at three days.-The information corresponding to day D that the OS will publish on day D + 4 is as follows:

Production power balance.

9.3 Monthly Information. -Monthly the OS will publish the following information:

Electrical System Operation Statistics.

Availability of the generation thermal equipment.

Rate of unavailability of lines, transformers, and reactive energy compensation elements (reactances and capacitors) of the transport network.

Incident statistics.

Non-supplied power quality (ENS) and average interrupt time (TIM) service quality.

9.4 Annual information. -The OS will publish the following information annually:

Availability of the generator equipment.

Availability of the transport network.

Annual evolution of the shorting power at the knots of the transport network.

ENS and TIM service quality.

Seasonal thermal limits of the transport network.

In addition, the OS will keep historical and available strings available from:

Power installed on the system.

Energy generated by both the ordinary regime and the special regime.

Demand for the electrical system.

Hydroelectric producible.

Hydroelectric reserves.

The availability rates for the generator equipment.

Transport network availability rates.

10. Analysis and incident information.

10.1 Incidents. -Events that define those incidents of the electrical system that are the object of information, in the scope of this procedure, by the subject holder of the facilities affected or the person responsible for the supply to the final consumers concerned are as follows:

(a) The loss of one or more transport facilities and/or other elements of the electrical system (generation and/or transport-distribution transformation) where this results in a violation of the operating criteria and electrical system security as set out in the relevant operating procedure or direct loss of supply.

b) Any other circumstances that result in:

a) Damage to any of the elements of the electrical system.

b) Failure, degradation, or improper performance of the protection system, automatisms or any other system that does not require manual intervention by the operator.

(c) Any act that may be suspected of electronic or physical sabotage, terrorism directed against the electrical system or its components with intent to disrupt the supply, or to reduce the reliability of the system power as a whole.

10.2 Communication to the Operator of the System. -In the event that there is an incident of those defined in the previous paragraph, the subject holder of the facilities or responsible for the supply concerned shall provide the and within 2 hours the best information available on the causes and effects of the event. This information which constitutes the preliminary report of the incidence shall contain at least the aspects (a), (b), (c) and (d) listed in Annex 3 which are applicable.

The OS may, when it deems necessary, carry out additional consultations in order to clarify the content of the preliminary report, leaving the issuer of the same obligation to attend the consultation at that time or as soon as have the required additional information.

When the OS determines that the event constitutes a significant incident for the electrical system, it shall notify the holder or representative of the installation or the person responsible for the supply to the consumers. The final Such a subject shall submit a written report to the OS within a period not exceeding 15 working days from the request. This report shall review and complete the information referred to in the preliminary report (Annex 3) and include any actions identified by the subject to avoid or minimise the effect of similar incidents that may occur in the future.

10.3 System Operator Communication.-When an incident occurs as defined in section 10.1, the OS will include the corresponding information in a "Daily Incident Party" that will be made available to the market subjects within 12 hours of the day following the occurrence of the market.

When the OS considers an incident of special relevance, it will produce a written report, once the final information of the report is available. This report shall include the measures to be taken to avoid repetition of the impact or the minimisation of its consequences in the event of a similar situation in the future. This report shall be forwarded to the subjects concerned, to the NEC and to the MINECO, within a period not exceeding 60 working days after the occurrence of the incident.

Reports corresponding to the most significant incidents will be presented and analyzed at the meetings of the Incident Analysis Group that will be convened by the System Operator.

10.4 Joint Research. -For those incidents in which, due to their importance or nature, the OS deems it necessary, it will propose as soon as possible the realization of a joint analysis with the other subjects involved or affected. The results of that analysis will be incorporated into the report that the OS produces on the incident.

11. System Operator liability clearance information.

11.1 Confidential information.-The confidential information relating to the settlements made by the OS is the one that communicates to the market subjects individually without access to the rest of the market. of subjects.

All processes associated with this information are defined in the liquidations procedures.

11.2 Public Information. The aggregate settlement information made available to the subjects shall also be made available to the general public on the same day.

ANNEX I

Structural database content

General notes and abbreviations

As a general rule, data must be expressed in units of the international system unless otherwise expressly stated.

The impedance data should indicate the voltage to which they are referred or the base values, if any.

Annex I structure

This annex is organized according to the following structure:

1. Production system.

1.1 Embalses.

1.2 Central and regular hydraulic groups.

1.2.1 Installation general and hydraulic data.

1.2.2 Data for each group.

1.2.3 Secondary regulation data (in the case of generation units participating in the secondary secondary regulation service).

1.2.4 Data required for service replacement plans (in the case of power stations over 50 MW or connected to the transport network).

1.2.5 Data of the group transformers (in the case of power stations of more than 50 MW or connected to the transport network).

1.2.6 Data from the evacuation line or cable (in the case of power stations of more than 50 MW or connected to the transport network).

1.2.7 Data from the Protections.

1.2.8 Main data for voltage control equipment (in the case of power stations of more than 10 MW or connected to the transport network).

1.2.9 Supplementary voltage control service (in the case of connection to the transport network).

1.3 Ordinary-speed thermal units.

1.3.1 General installation data.

1.3.2 Data for each generator.

1.3.3 Main turbine data and primary regulatory equipment.

1.3.4 Secondary regulation data (in the case of generation units participating in the secondary secondary regulation service).

1.3.5 Data for programming and tertiary regulation.

1.3.6 Main data for voltage control equipment (in the case of power stations of more than 10 MW or connected to the transport network).

1.3.7 Complementary voltage control service (in the case of connection to the transport network).

1.3.8 Data required for service replacement plans (in the case of power stations over 50 MW or connected to the transport network).

1.3.9 Data for group transformers (in the case of power stations over 50 MW or connected to the transport network).

1.3.10 Data from the evacuation line or cable (in the case of power stations of more than 50 MW or connected to the transport network).

1.3.11 Data from the Protections.

1.4 Special Regime Units.

1.4.1 Photovoltaics above 50 kW and up to 1 MW.

1.4.2 Non-wind groups larger than 1 MW or connected to the transport network or participating individually or in a pooled manner in the system adjustment services. (The photovoltaic plants of more than 1 MW or connected to the transport network are included under this heading).

1.4.2.1 Installation and group data.

1.4.2.2 Secondary regulation data (in the case of generation units participating in the secondary regulation service).

1.4.2.3 Data for tertiary programming and regulation (in non-hydraulic groups and in case of participation in system adjustment services).

1.4.2.4 Data required for service replacement plans (in case of generators or pool of generators of more than 50 MW of total power or connected to the transport network).

1.4.2.5 Data for group transformers (in the case of generators or pool of generators of more than 50 MW or connected to the transport network).

1.4.2.6 Data from the evacuation line or cable (in the case of generators or pool of generators of more than 50 MW or connected to the transport network).

1.4.2.7 Data from the Protections.

1.4.2.8 Main data for voltage control equipment.

1.4.2.9 Supplementary voltage control service in the case of connection to the transport network.

1.4.3 Wind Parks.

1.4.3.1 Features of each park.

1.4.3.2 Network connection transformer data.

1.4.3.3 Network connection cable or line data.

1.4.3.4 Data from the Protections.

1.4.3.5 Additional data in the case of parks connected to a transport network.

1.4.3.5.1 Characteristics of each park.

1.4.3.5.2 Supplementary voltage control service.

1.4.3.5.3 Park transformer data.

1.4.3.5.4 Data from the line or escape cable from each park.

1.4.3.5.5 Network connection transformer data.

1.4.3.5.6 Evacuation line or cable data.

1.4.3.5.7 Data from the Protections.

2. Transport network.

2.1 Substations.

2.2 Parks.

2.3 Lines and cables.

2.4 Transformers.

2.5 Active or reactive power control elements.

3. Consumer installations connected to the transport network.

4. Observable network.

4.1 Substations.

4.2 Parks.

4.3 Lines and cables.

4.4 Transformers.

4.5 Reactive power control elements.

1. Production system.

1.1 Embalses.

Name of the reservoir.

Company or proprietary or concessionary companies:

Name.

NIF/CIF.

Address.

Percentage of participation.

Basin (river).

Situation: province, municipal term, place or land.

Date of termination.

Power in electrical power (MWh).

Historical series of partial contributions to the reservoir in monthly and weekly terms (m3).

Maximum volume (hm3).

Minimum volume (hm3).

Reservoir cote curve based on useful volume (minimum 3. degree).

Maximum farm (m).

Minimum farm (m).

Ecological minimum flow to keep downstream.

Regulatory coefficient (days), defined as the ratio between the reservoir volume and the average annual contribution to the reservoir.

Reservoir Emptying Time (hours) with turban at full load of the center itself.

Usage (Hydroelectric, Mixed).

Operating constraints (detettions, watering, etc).

1.2 Central and regular hydraulic groups.

1.2.1 Installation general and hydraulic data.

1.2.1.1 Central to less than 10 MW of power and not connected to the transport network.

Name of the Central.

Address of the Central: municipality, postal code and province.

Company or proprietary companies:

Name.

NIF/CIF.

Address.

Percentage of participation.

Enterprise or exploitative companies:

Name.

NIF/CIF.

Address.

Basin (river) in which the power plant is located.

The associated reservoir.

Substation/network connection park (Name, kV).

Hydraulic Management Unit to which you belong, if any.

Number of groups.

Rated power.

nominal flow (m3/s).

Net nominal jump (m).

1.2.1.2 Central to more than 10 MW or connected to the transport network.

Name of the Central.

Address of the Central: municipality, postal code and province.

Geographical location (requests for access to the transport network or distribution network with influence on the transport network): plans (minimum detail of particular situation E 1:50,000 and general situation E 1:200,000) and significant distances (to lines and knots of connection to the network).

UTM Coordinates of the installation (give a reference point).

Unifilar diagram with all the components of the network link installation (requests for access to the transport network or for voltage distribution networks exceeding 100 kV with influence on the transport network).

Company or proprietary companies:

Name.

NIF/CIF.

Address.

Percentage of participation.

Enterprise or exploitative companies:

Name.

NIF/CIF.

Address.

Basin (river) in which the power plant is located.

Hydraulic subsystem schema.

The associated reservoir.

Substation/network connection park (Name, kV).

Hydraulic Management Unit to which you belong, if any.

Estimated unavailability rates for maintenance.

Estimated unavailability rates for other causes.

Driving Channel/Pressure Gallery (SI/NO). If yes, length (s) and diameter (s).

Deposit or charging chamber (SI/NO). If yes, volume.

Forced Pipeline (SI/NO). If yes, length (s) and diameter (s).

Number of groups.

Rated power.

nominal flow (m3/s).

Net nominal jump (m).

Maximum turbination flow (m3/s).

Minimum flow rate (m3/s).

Maximum gross jump (m).

Minimum gross jump (m).

Maximum net jump (m).

Minimum net jump (m).

Losses in flow-based pipelines: Perdconduccio= f (Q2).

Throughput curves based on flow rate and net jump (alternative: power tables for different net jumps and different flow rates for each net jump).

For reversible or pumping groups:

Rated power.

Nominal effective height (m).

Nominal Pump Flow (m3/s).

Maximum pump flow (m3/s).

Minimum pumping flow (m3/s).

Loss in aspiration and drive based on flow rate: Perdpipeline= f (Q2).

Performance curves based on the pumped flow and the manometric height (alternative: power tables for different manometric heights and different flow rates for each manometric height).

Pumping Accumulation Index (%), defined as the ratio of the electrical energy that can occur with the water accumulated by pumping and the energy consumed for its elevation.

Additional data in the case of power stations connected to the transport network:

Physical diagram (general scheme at site) of the link installation.

One-to-one detail diagram of power equipment from the different generation units to the point of connection to the network.

Unifilar installation protection scheme.

1.2.2 Data for each group.

1.2.2.1 Central power stations of less than 10 MW and not connected to the transport network.

Identification number in the RAIPEE (Administrative Registry of Electrical Power Production Facilities).

On-or-off date (forecast if applicable).

Apparent power in alternator (MVA) borders.

Rated power in turbination (MW).

nominal flow (m3/s).

Nominal jump (m).

Net technical minimum, that is, in central bars (MW).

For reversible or pumping groups:

Rated power.

Nominal effective height (m).

Nominal Pump Flow (m3/s).

Availability of primary regulation or speed regulation (SI/NO). If yes, indicate:

Regulator sensitivity (mHz). It must not be greater than 10 mHz.

Regulator voluntary dead band (mHz): confirm that the adjusted value is zero.

In case of no primary regulation of your own, provide documentation that accredits the service delivery by another generating unit, indicating:

Unit that provides the service.

Insensitivity confirmation not greater than 10 mHz.

Null voluntary dead-band commit.

1.2.2.2 Central over 10 MW of power or connected to the transport network.

Identification number in the RAIPEE (Administrative Registry of Electrical Power Production Facilities).

On-or-off date (forecast if applicable).

Turbine type.

Nominal speed (rpm).

Rated power in turbination (MW).

nominal flow (m3/s).

Net nominal jump (m).

Net technical minimum, that is, in central bars (MW).

Maximum turbination flow (m3/s).

Minimum flow rate (m3/s).

Maximum gross jump (m).

Minimum gross jump (m).

Maximum net jump (m).

Minimum net jump (m).

Losses in flow-based pipelines: Perdconduccio= f (Q2).

Throughput curves based on flow rate and net jump (alternative: power tables for different net jumps and different flow rates for each net jump).

For reversible or pumping groups:

Type of pump.

Rated power.

Nominal speed (rpm).

Nominal effective height (m).

Nominal Pump Flow (m3/s).

Maximum pump flow (m3/s).

Minimum pumping flow (m3/s).

Loss in aspiration and drive based on flow rate: Perdpipeline= f (Q2).

Performance curves based on the pumped flow and the manometric height (alternative: power tables for different manometric heights and different flow rates for each manometric height).

Apparent power in alternator (MVA) borders.

Maximum Full Load Reactive Generation (MVAr) in b.c.

Maximum Technical Minimum Reactive Generation (MVAr) in b.c.

Maximum full-load reactive absorption (MVAr) in b.c.

Maximum Technical Minimum Reactive Absorption (MVAr) in b.c.

Rated power factor.

Rotating set inertia constant: electric machine, exciter, and turbine.

Capability as synchronous compensator (SI/NO).

Power absorbed in operation as synchronous compensator (MW).

Top turbine and primary regulatory equipment data:

Turbine features: manufacturer and model.

Availability of primary regulation or speed regulation (SI/NO).

In case of no primary regulation of your own, provide documentation that accredits the service delivery by another generating unit, indicating:

Unit that provides the service.

Insensitivity confirmation not greater than 10 mHz.

Null voluntary dead-band commit.

In case of your own primary regulation, please indicate:

Characteristics of the local mechanism that supplies the watchword to the regulator: motorized potentiometer, digital slogan, ...

Permanent status:

Adjustment range.

Adjusted value.

Adjusted value telemedidability.

Speed of power variation in MW/s, by frequency variation. Insensitivity of the regulator (mHz). It must not be greater than 10 mHz.

Regulator voluntary dead band (mHz):

Adjustment range.

Adjusted value: confirm that it is zero.

Adjusted value telemedidability.

Regulator characteristics: manufacturer, type of control (PID series compensator, resupply compensation using transient staticism, ...) and technology (hydraulic, electrohydraulic ...).

Dynamic offsets: dynamic compensation transfer function (transient staticism, series compensator, ...). The range of each parameter and its setting or watchword value must be specified.

The turbine-speed regulator block scheme and the corresponding values of the parameters that are represented in the schemas. This information will be provided as follows:

Through a model included in the list of dynamic models supported by the OS, and which will be provided by the OS itself, or through a model not included in the previous list as long as it meets the characteristics and conditions set out in document to the effect developed by the OS.

In both cases, it must be accompanied by a validation report on the suitability of the model to represent the speed-turbine regulator according to the conditions set out in the document to the effect produced by the OS.

Generation Nominal Voltage (kV).

Maximum generation voltage (kV).

Minimum generation voltage (kV).

Non-saturated synchronous, transient, and subtransient reactances for direct axis and transverse axis in machine base (Xd, Xq, X'd, X'q, X''d yX''q. Symbology compliant a standard UNE-EN 60034-4).

Short-circuit transient and subtransient time constants for both direct and transverse (s) (T'd, T'q, T ''d , and T ''q. Symbology as standard UNE-EN 60034-4).

Open-circuit transient and subtransient time constants for both direct and transverse axis (s) (T'd0, T'q0, T ''d0 , and T ''q0. Symbology as standard UNE-EN 60034-4).

Unsaturated leak reactance (p.u.) (Xl).

Saturation of machine to voltage 1.0 p.u., as shown in Figure 1.

Saturation of machine to voltage 1.2 p.u., as shown in Figure 1.

P-Q Capacity Curves (Generator Operating Limits).

An image appears in the original. See the official and authentic PDF document.

1.2.3 Secondary regulation data (in the case of generation units participating in the secondary secondary regulation service).

Regulatory zone to which you belong.

Detailed information of the connection of the regulatory system with the AGC: characteristics of the signal signal, signal processing, limits, ...

Maximum and minimum active power of regulation in b.a. (MW).

Limitations on upload and load drop on MW/min: adjustment range and slogan values for continuous ramp and step.

1.2.4 Data required for service replacement plans (in the case of power stations over 50 MW or connected to the transport network).

Stand-alone startup capacity.

Own media to energize the auxiliary services needed for startup:

Battery.

Diesel Group.

Other.

Single-circle diagrams.

Autonomy time (hours).

Boot type:

By remote control.

Local operation (staff time availability will be indicated).

The minimum guaranteed operating time continued at full load during the replenishment process (minimum water reserves).

Possibility of performing a certain number of consecutive starts in a given time (in case of possible shots during the replacement process): number of start and stop cycles, and cycle duration.

Minimum number of groups to operate in parallel.

Cascade startup capability for a set of groups.

Island operating capacity. Minimum market bag that is capable of feeding the group in island situation.

Ability to remain stable after a disconnect from the outside network with sudden loss of full load, only feeding its own consumption.

1.2.5 Data of the group transformers (in the case of power stations of more than 50 MW or connected to the transport network).

1.2.5.1 Central over 50 MW not connected to the transport network.

rated power (MVA).

Nominal voltage (kV) of primary and secondary.

Connection group.

Loss due to load (kW).

Short Circuit Voltage (%).

Homopolar impedance (% on machine base).

1.2.5.2 Central connected to the transport network. -See transport transformers.

1.2.6 Data from the evacuation line or cable (in the case of power stations of more than 50 MW or connected to the transport network).

1.2.6.1 Central over 50 MW not connected to the transport network: See observable network lines and cables.

1.2.6.2 Central attached to the transport network: See transport lines and cables.

1.2.7 Data from the Protections.

1.2.7.1 Power stations less than or equal to 50 MW that are not connected to the transport network.

Compliance with the General Protection Criteria (which are included in the procedure for establishing the General Protection Criteria) against internal disturbances to the plant (yes/no). Indicate particularities, if any.

Minimum frequency protection: settings and compliance with the procedure that the Safety Plans are set for.

Overfrequency protection. Adjustments.

In case the critical time in the connection node to the network is less than 1 second, indicate:

Short-circuit protection scheme in the network-main transformer stretch.

Compliance with the General Protection Criteria.

1.2.7.2 Central over 50 MW or connected to the transport network.

Compliance with the General Protection Criteria (which are included in the procedure for establishing the General Protection Criteria) against internal disturbances to the plant (yes/no). Indicate particularities, if any.

Minimum Voltage Relays: Settings.

Minimum frequency protection: settings and compliance with the procedure that the Safety Plans are set for.

Overfrequency protection. Adjustments.

Shot by Overspeed. Firing value.

In case the critical time in the connection node to the network is less than 1 second, indicate:

Short-circuit protection scheme in the network-main transformer stretch.

Compliance with the General Protection Criteria.

Unifilar installation protection scheme.

1.2.7.3 Additional data in the case of power stations connected to the transport network.

1.2.7.3.1 Central Protections.

Network short-circuit support protection: indicate relay type (s), adjustment criteria and values, and coordination status (SI/NO) with network protections.

Protection from loss of syncism: indicate type of protection, number of slides for the shot, and if the group is left over auxiliaries.

Overvoltage relay: settings.

Reverse sequence protection: indicate the coordination status of this protection with the single-phase reengagement and the network pole discordance relays.

Sync conditions for coupling. Existing automatisms and settings.

1.2.7.3.2 Protections associated with the link installation.

Network short-circuit support protection: indicate relay type (s), adjustment criteria and values, and coordination status (SI/NO) with network protections.

Short-circuit protection scheme in the network-transformer stretch of generation. Compliance with the General Protection Criteria.

Minimum voltage relay: settings.

1.2.7.3.3 Teleshooting at network contingencies.

Teleshooting capacity (SI/NO).

The tele-firing time since the signal is received.

Teleshooting logic and switches or selectors that includes.

1.2.8 Main data for voltage control equipment (in the case of power stations of more than 10 MW or connected to the transport network).

Brief description of the voltage regulator-excitation, which will include the name and type of the regulator.

Block scheme, and the corresponding values of the parameters that are represented in the schemes, of the voltage-excitedess and the power stabiliser system (PSS), if they have this device. information will be provided as follows:

Through a model included in the list of dynamic models supported by the OS, and that will be provided by the OS itself,

Or through a model not included in the above list provided that it meets the characteristics and conditions set out in document to the effect elaborated by the OS.

In both cases, it must be accompanied by a validation report on the suitability of the model to represent the voltage regulator and the power stabiliser system (PSS), in accordance with the conditions set out in the document to the effect developed by the OS.

1.2.9 Supplementary voltage control service (in the case of connection to the transport network).

explicit declaration of compliance with mandatory voltage control requirements established in the operating procedure in which the Supplementary Tension Control Service or non-compliance is described, in its case, and its justification.

In the case of reversible generator/motor groups, complete the data required in Annex 1 of PO 7.4 for each of the modes of operation.

In the case of generating groups and reversible groups that have the capacity to function as synchronous compensators, the technical operating requirements shall be indicated, and the time required for their entry into operation.

The possibility, if any, of telematic the groups must be indicated so that the excitation slogan and/or the takes of the group's output transformer can be modified from the generation office of the titular subject or group representative, or from the appropriate control center.

1.3 Ordinary-speed thermal units.

1.3.1 General installation data.

1.3.1.1 Central to less than 10 MW of power and not connected to the transport network.

Denomination of the central.

Company or proprietary companies:

Name.

NIF/CIF.

Address.

Percentage of participation.

Enterprise or exploitative companies:

Name.

NIF/CIF.

Address.

Identification number in the RAIPEE.

Head office: municipality, postal code and province.

On or off date (forecast, if any).

Primary and alternate fuels.

Substation/network connection park (Name, kV).

1.3.1.2 Central over 10 MW or connected to the transport network.

Denomination of the central.

Company or proprietary companies:

Name.

NIF/CIF.

Address.

Percentage of participation.

Enterprise or exploitative companies:

Name.

NIF/CIF.

Address.

Identification number in the RAIPEE.

Head office: municipality, postal code and province.

On or off date (forecast, if any).

Primary and alternate fuels.

Substation/network connection park (Name, kV).

Geographical location (access requests): planes (minimum detail of particular situation E 1:50,000 and general situation E 1:200,000) and significant distances (to lines and knots of connection to the network).

UTM Coordinates of the installation (give a reference point).

General configuration of the installation, indicating in its case characteristics of coupling between elements (e.g. gas turbines, steam turbines and alternators), as well as modularity and operating flexibility.

Estimated unavailability rates for maintenance and other causes (annual and seasonal indices if applicable).

Fuel consumption structure on startup: percentage in terms of consumption of each of the fuels used.

Startup Formula: Expression that allows this consumption to be calculated based on startup time (the elapsed since the last stop):

Ct = C0 x (1-e-t/τ)

Heat consumption on cold start of each thermal unit and set (termine) C0.

Net efficiency (net specific consumption) referred to PCI for each thermal unit and the set for different load regimes (kWh/kcal).

Maximum primary and alternate fuel storage capacity (T).

Power reserve (fuel storage park) (MWh) for primary and alternative fuels.

Maximum number of operating hours at full load without external supply for primary and alternate fuels.

Planned operating system.

Additional data in the case of power stations connected to the transport network.

Unifile diagram with all the components of the network link installation (access requests).

Physical diagram (general scheme at site) of the link installation.

One-to-one detail diagram of power equipment from the different generation units to the point of connection to the network.

Uniform installation protection schemes up to the point of connection to the network, including auxiliary and transformer start-up services, if any.

1.3.2 Data for each generator.

1.3.2.1 Central power stations of less than 10 MW and not connected to the transport network.

Apparent power installed (MVA).

Net active power installed in b.c. (MW).

Technical minimum in b.c. (MW).

Maximum Technical Minimum Reactive Generation (MVAr) in b.a.

Maximum Technical Minimum Reactive Absorption (MVAr) in b.a.

1.3.2.2 Central to more than 10 MW or connected to the transport network. -In the case of generators dependent on each other, as may be the combined cycle members, also provide the active and reactive power data, for the various possible configurations of both permanent and short duration, for example, with off-duty steam turbine.

Apparent power installed (MVA).

Generation Nominal Voltage (kV).

Maximum generation voltage (kV).

Minimum generation voltage (kV).

Active power installed in b.a. (MW).

Net active power installed in b.c. (MW).

Effective net active power of winter in b.c. (MW).

Effective net active power of summer in b.c. (MW).

Technical minimum in b.a. (MW).

Technical minimum in b.c. (MW).

Special technical minimum in b.a. (MW).

Special technical minimum in b.c. (MW).

The time that the minimum special technician (h) can be maintained.

Maximum Full Load Reactive Generation (MVAr) in b.a.

Maximum Technical Minimum Reactive Generation (MVAr) in b.a.

Maximum full-load reactive absorption (MVAr) in b.a.

Maximum Technical Minimum Reactive Absorption (MVAr) in b.a.

Auxiliary services consumption in b.a. at full load, active power (MW).

Auxiliary services consumption in b.a. at full load, reactive power (MVAr).

Auxiliary services consumption in at least technical, active power (MW).

Auxiliary services consumption in at least technical, reactive power (MVAr).

Rated power factor.

Non-saturated synchronous, transient, and subtransient reactances for direct axis and transverse axis in machine base (Xd, Xq, X'd, X'q, X''d yX''q. Symbology as standard UNE-EN 60034-4).

Transient and subtransient time constants of short circuit for both direct and transverse axis (s). (T'd, T'q, T ''d , and T ''q. Symbology as standard UNE-EN 60034-4).

Transient and subtransient open-loop time constants for both direct and transverse axis (s). (T'd0, T'q0, T ''d0 , and T ''q0. Symbology as standard UNE-EN 60034-4).

Rotating set inertia constant: electric machine, exciter, and turbine.

Unsaturated leakage reactance (p.u.). (Xl).

Saturation of machine to voltage 1.0 p.u., as shown in Figure 1.

Saturation of machine to voltage 1.2 p.u., as shown in Figure 1.

P-Q Capacity Curves (Operating Limits).

An image appears in the original. See the official and authentic PDF document.

1.3.3 Main turbine data and primary regulatory equipment.

1.3.3.1 Central to less than 10 MW and not connected to the transport network.

Availability of primary regulation or speed regulation (SI/NO).

In case of no primary regulation of your own, provide documentation that accredits the service delivery by another generating unit, indicating:

Unit that provides the service.

Insensitivity confirmation not greater than 10 mHz.

Null voluntary dead-band commit.

Regulator sensitivity (mHz). It must not be greater than 10 mHz.

Regulator voluntary dead band (mHz):

Adjustment range.

Adjusted value: confirm that it is zero.

Adjusted value telemedidability.

1.3.3.2 Central to more than 10 MW or connected to the transport network. -In the case of multi-axle combined cycles, the information requested here shall be sent separately for each gas and steam turbine.

Gas turbine characteristics (if any): manufacturer and model.

Steam turbine characteristics (if any): manufacturer and model.

Availability of primary regulation or speed regulation (SI/NO).

In case of no primary regulation of your own, provide documentation that accredits the service delivery by another generating unit, indicating:

Unit that provides the service.

Insensitivity confirmation not greater than 10 mHz.

Null voluntary dead-band commit.

In case of self-regulation, please indicate:

Characteristics of the local mechanism that supplies the watchword to the regulator: motorized potentiometer, digital slogan, ...

Permanent status:

Adjustment range.

Adjusted value.

Adjusted value telemedidability.

Speed of power variation in MW/s, by frequency variation.

Regulator sensitivity (mHz). It must not be greater than 10 mHz.

Regulator voluntary dead band (mHz):

Adjustment range.

Adjusted value: confirm that it is zero.

Adjusted value telemedidability.

Characteristics of the regulator (or regulators, if any): manufacturer, type of control (PID series compensator, compensation for feedback via transient staticism, ...) and technology (hydraulic, electrohydraulic ...).

Dynamic offsets: dynamic compensation transfer function (transient staticism, series compensator, ...). The range of each parameter and its watchword value must be specified.

Regulator block scheme (or the regulators, if any) of the turbine-speed and the corresponding values of the parameters that are represented in the schemas. This information shall be provided, in the case of installations of more than 10 MW or connected to the transport network, as follows:

Through a model included in the list of dynamic models supported by the OS, and that will be provided by the OS itself,

Or through a model not included in the above list provided that it meets the characteristics and conditions set out in document to the effect elaborated by the OS.

In both cases, a validation report on the suitability of the model to represent the turbine-speed regulator, in accordance with the conditions set out in the document, shall be accompanied by the OS.

1.3.4 Secondary regulation data (in the case of generation units participating in the secondary secondary regulation service).

Regulatory zone to which you belong.

Detailed information of the connection of the regulatory system with the AGC: characteristics of the signal signal, signal processing, limits, ...

Maximum and minimum active power of regulation in b.a. (MW) for different stable operating points, if applicable.

Limitations on upload and load drop on MW/min: adjustment range and slogan values for continuous ramp and step.

1.3.5 Data for programming and tertiary regulation. -In the case of generators dependent on each other, as the combined cycle members can be, also contribute the requested data, for the different configurations The invention relates to a method for operating the gas turbine and the steam

.

Boot time:

Cold (from boot order to ready for synchronization).

Hot (from boot order to ready for synchronization).

Minimum programming boot time.

From synchronization to minimum technical (min).

From synchronization to full load (min).

Minimum programming stop time (from full load to disconnection) (min).

Maximum up-ramp of tertiary regulation (MW in 15 min).

Top down ramp of tertiary regulation (MW in 15 min).

1.3.6 Main data for voltage control equipment (in the case of power stations of more than 10 MW or connected to the transport network). -In the case of multi-axle combined cycles, the information requested shall be sent separately for each gas and steam turbine generator.

Brief description of the voltage regulator-excitation, which will include the name and type of the regulator.

Block schema, and corresponding values of the parameters that are represented in the schemas, of the voltage-excitedess and the stabilizer system (PSS) regulators, if they have this device. This information shall be provided, in the case of installations of more than 10 MW or connected to the transport network, as follows:

Through a model included in the list of dynamic models supported by the OS, and that will be provided by the OS itself,

Or through a model not included in the above list provided that it meets the characteristics and conditions set out in document to the effect elaborated by the OS.

In both cases it must be accompanied by a validation report on the suitability of the model to represent the voltage regulator and the power stabiliser system (PSS), in accordance with the conditions set out in the document to the effect developed by the OS.

1.3.7 Complementary voltage control service (in the case of connection to the transport network).

Explicit declaration of compliance with the mandatory voltage control requirements set out in the procedure described in the Complementary Tension Control Service of the transport network or defaults, if any, and their justification.

In the case of generating groups and reversible groups that have the capacity to function as synchronous compensators, the technical operating requirements shall be indicated, and the time required for their entry into operation.

The possibility, if any, of telematic the groups must be indicated so that the excitation slogan and/or the takes of the group's output transformer can be modified from the generation office of the titular subject or group representative, or from the appropriate control center.

1.3.8 Data required for service replacement plans (in the case of power stations over 50 MW or connected to the transport network).

SSAA power:

Simplified schema and description of the SSAA power process in the following assumptions:

Normal.

Boot.

Other Alternatives (Diesel/Bater/Otras) Groups.

SSAA Power Voltage.

Auxiliary services consumption in b.a. for group stop, active power (MW).

Auxiliary services consumption in b.a. for group stop, reactive power (MVAr).

Auxiliary services consumption in b.a. for startup, active power (MW). Specify different possibilities: Cold start/Hot start.

Auxiliary services consumption in b.a. for startup, reactive power (MVAr). Specify different possibilities: Cold start/Hot start.

Stand-alone startup capacity.

Own media to energize the auxiliary services needed for startup:

Battery.

Diesel Group.

Other.

Single-circle diagrams.

Autonomy time (hours).

Boot type:

By remote control.

Local operation (staff time availability will be indicated).

The minimum guaranteed operating time continued at full load during the replenishment process (minimum fuel reserves).

Possibility of performing a certain number of consecutive starts in a given time (in case of possible shots during the replacement process): number of start and stop cycles, and cycle duration.

Cascade startup capability for a set of groups.

Reconnect the group to the network.

Minimum cold start time (since power is received in the SSAA until ready for synchronization).

Minimum hot start time (since power is received in the SSAA until ready for synchronization).

Maximum stop time for the boot to be hot.

Ability to remain stable after a disconnect from the outside network with sudden loss of full load, only feeding its own consumption. (Yes/No. Description).

Island operating capacity. Minimum market bag that is capable of feeding the plant in island situation.

Sync conditions for coupling. Existing automatisms and settings.

Other data:

Characteristics of the engines and loads of ancillary services and data on protections and adjustments, if any.

Dependence on non-fuel supply infrastructures for the reorder process.

1.3.9 Data for group transformers (in the case of power stations over 50 MW or connected to the transport network).

1.3.9.1 Central over 50 MW not connected to the transport network.

rated power (MVA).

Nominal voltage (kV) of primary and secondary.

Connection group.

Loss due to load (kW).

Short Circuit Voltage (%).

Homopolar impedance (% on machine base).

1.3.9.2 Central connected to the transport network. -See transport transformers.

1.3.10 Data from the evacuation line or cable (in the case of power stations of more than 50 MW or connected to the transport network).

1.3.10.1 Central over 50 MW not connected to the transport network. -See observable network lines and cables.

1.3.10.2 Central attached to the transport network. -See transport lines and cables.

1.3.11 Data from the Protections.

1.3.11.1 Central less than 50 MW that are not connected to the transport network.

Compliance with the General Protection Criteria (which are included in the procedure for establishing the General Protection Criteria) against internal disturbances to the plant (yes/no). Indicate particularities, if any.

Minimum frequency protection: settings and compliance with the procedure that the Safety Plans are set for.

Overfrequency protection. Adjustments.

In case the critical time in the connection node to the network is less than 1 second, indicate:

Short-circuit protection scheme in the network-main transformer stretch.

Compliance with the General Protection Criteria.

1.3.11.2 Central over 50 MW or connected to the transport network.

Compliance with the General Protection Criteria (which are included in the procedure for establishing the General Protection Criteria) against internal disturbances to the plant (yes/no). Indicate particularities, if any.

Auxiliary services, minimum voltage and/or minimum frequency relays: indicate adjustments and for the minimum voltage relay phases in which it measures and trigger logic.

Minimum group frequency protection: settings and compliance with the procedure that the Safety Plans are set for.

Overfrequency protection (yes/no). Adjustments, if any.

Shot by Overspeed. Firing value.

In case the critical time in the connection node to the network is less than 1 second, indicate:

Short-circuit protection scheme in the network-main transformer stretch.

Compliance with the General Protection Criteria.

1.3.11.3 Additional data in the case of power stations connected to the transport network.

1.3.11.3.1 Protections of the Central.

Network short-circuit support protection: indicate relay type (s), adjustment criteria and values, and coordination status (SI/NO) with network protections.

Auxiliary services, minimum voltage and/or minimum frequency relays: indicate adjustments and for the minimum voltage relay phases in which it measures and trigger logic.

Protection from loss of syncism: indicate type of protection, number of slides for the shot, and if the group is left over auxiliaries.

Overvoltage relay: settings.

Reverse sequence protection: Indicate coordination status with the single-phase reengagement and the network's pole discordance relays.

Sync conditions for coupling. Existing automatisms and settings.

1.3.11.3.2 Protections associated with the link installation.

Network short-circuit support protection: indicate relay type (s), adjustment criteria and values, and coordination status (SI/NO) with network protections.

Short-circuit protection scheme in the network-group transformer stretch. Compliance with the General Protection Criteria.

Minimum voltage relay: settings.

1.3.11.3.3 Teleshooting at network contingencies.

Teleshooting capacity (SI/NO).

Type of telephoto (generation switch or fast-valve opening).

End power and download time in cases of rapid load reduction (fast-valve) and in general in non-instant processes, such as in combined cycles, the response of the steam turbine to partial telefiring of gas turbines.

The tele-firing time since the signal is received.

Teleshooting logic and switches or selectors that includes.

1.4 Special Regime Units.

1.4.1 PV plants greater than 50 KW and up to 1 MW.

Name of the central.

Catastral number of the farm.

Company or proprietary companies:

Name.

NIF/CIF.

Address.

Percentage of participation.

Identification number in the RAIPEE.

Head office: municipality, postal code and province.

On or off date (forecast, if any).

Distributor Company.

1.4.2 Non-wind groups larger than 1mw or connected to the transport network or participating individually or in a grouped manner in the system adjustment services (including under this heading the most-developed photovoltaic plants). 1 MW).

1.4.2.1 Installation and group data.

1.4.2.1.1 General.

Name of the central.

Geographical location (requests for access to the transport network or distribution network with influence on the transport network): plans (minimum detail of particular situation E 1:50,000 and general situation E 1:200,000) and significant distances (to lines and knots of connection to the network).

Company or proprietary companies:

Name.

NIF/CIF.

Address.

Percentage of participation.

Identification number in the RAIPEE.

The offering unit to which you belong, if any.

Head office: municipality, postal code and province.

On or off date (forecast, if any).

Type of Central.

Grant Date on Special Regime.

The final year of the concession.

Applicable regulations.

Distributor Company.

Substation/network connection park (Name, kV).

Type of installation according to Royal Decree 661/2007 or alternative regulations that are applicable.

Number of groups.

Fuel.

For hydraulic groups:

Jump (m).

Maximum flow (m3/s).

Throttling regime (fluid, daily, weekly).

Basin (river).

Rotating set inertia constant: electric machine, exciter, and turbine.

Data from energy storage systems and support by complementary fuel in the case of manageable or manageable thermal power plants:

Energy storage method (steam, oil, salts ...).

Stored primary energy recovery time curves.

Stored Primary Energy Loss Curves.

Type of support with complementary fuel, power supply with said fuel and autonomy thereof (in hours at rated power).

Maximum power that can be supplied by the maximum storage and power system that you can accumulate.

% of the plant's over-dimension for storage.

Apparent power installed (MVA) of the generating units.

Host power to Royal Decree 661/2007 or alternative regulations that are applicable (MW).

Non-Host Power (MW).

Net active power and minimum technical (MW) available for the network: statistical distribution by tenths of powers or time energies poured into the network since the plant became operational or estimated.

For generations: Maximum electrical consumption (MW) of the plant, including industrial consumption.

Availability of primary regulation or speed regulation (SI/NO). If yes, please indicate:

Regulator sensitivity (mHz). It must not be greater than 10 mHz.

Regulator voluntary dead band (mHz): confirm that the adjusted value is zero.

In case of no primary regulation of your own, provide documentation that accredits the service delivery by another generating unit, indicating:

Unit that provides the service.

Insensitivity confirmation not greater than 10 mHz.

Null voluntary dead-band commit.

1.4.2.1.2 Additional data in the case of generators or pool of generators of more than 10 MW of total power-reception not received-or connected to the transport network.

1.4.2.1.2.1 General.

UTM Coordinates of the installation (give a reference point).

Unifile diagram with all the components of the network link installation.

Planned operating system (daily, weekly, seasonal cycles, if applicable).

Estimated unavailability rates for maintenance.

Estimated unavailability rates for other causes.

Maximum full load-reactive (MVAr) generation at the point of connection to the network.

Maximum Technical Minimum Reactive Generation (MVAr) at the point of connection to the network.

Maximum full-load reactive absorption (MVAr) at the point of connection to the network.

Maximum Technical Minimum Reactive Absorption (MVAr) at the network connection point.

1.4.2.1.2.2 Additional general for hydraulic power stations of more than 10 MW.

Hydraulic subsystem schema.

The associated reservoir.

Hydraulic Management Unit to which you belong, if any.

Driving Channel/Pressure Gallery (SI/NO). If yes, length (s) and diameter (s).

Deposit or charging chamber (SI/NO). If yes, volume.

Forced Pipeline (SI/NO). If yes, length (s) and diameter (s).

Number of groups.

nominal flow (m3/s).

Net nominal jump (m).

Maximum turbination flow (m3/s).

Minimum flow rate (m3/s).

Maximum gross jump (m).

Minimum gross jump (m).

Maximum net jump (m).

Minimum net jump (m).

Losses in flow-based pipelines: Perdconduccio = f (Q2).

Throughput curves based on flow rate and net jump (alternative: power tables for different net jumps and different flow rates for each net jump).

For reversible or pumping groups:

Rated power.

Nominal effective height (m).

Nominal Pump Flow (m3/s).

Maximum pump flow (m3/s).

Minimum pumping flow (m3/s).

Loss in aspiration and drive based on flow rate: Perdpipeline = f (Q2).

Performance curves based on the pumped flow and the manometric height (alternative: power tables for different manometric heights and different flow rates for each manometric height).

Pumping Accumulation Index (%), defined as the ratio of the electrical energy that can occur with the water accumulated by pumping and the energy consumed for its elevation.

1.4.2.1.2.3 Data for each generator.

Nominal voltage (kV).

Maximum generation voltage (kV).

Minimum generation voltage (kV).

Nominal speed.

Non-saturated synchronous, transient, and subtransient reactances for direct axis and transverse axis in machine base (Xd, Xq, X'd, X'q, X''d yX''q. Symbology as standard UNE-EN 60034-4).

Transient and subtransient time constants of short circuit for both direct and transverse axis (s). (T'd, T'q, T ''d , and T ''q. Symbology as standard UNE-EN 60034-4).

Transient and subtransient open-loop time constants for both direct and transverse axis (s). (T'd0, T'q0, T ''d0 , and T ''q0. Symbology as standard UNE-EN 60034-4).

Unsaturated leak reactance (p.u.) (Xl).

Saturation of the machine at voltage 1.0 p.u. (p.u.), as Figure 1.

Saturation of the machine at voltage 1.2 p.u. (p.u.), as Figure 1.

P-Q Capacity Curves (Operating Limits).

Top turbine data and primary regulatory equipment.

Turbine features: manufacturer and model.

In case of self-regulation please indicate:

Characteristics of the local mechanism that supplies the watchword to the regulator: motorized potentiometer, digital slogan, ...

Permanent status:

Adjustment range.

Adjusted value.

Adjusted value telemedidability.

Speed of power variation in MW/s, per frequency variation Insensitivity of the regulator (mHz). It must not be greater than 10 mHz.

Regulator voluntary dead band (mHz):

Adjustment range.

Adjusted value: confirm that it is zero.

Adjusted value telemedidability.

Regulator characteristics: manufacturer, type of control (PID series compensator, resupply compensation using transient staticism, ...) and technology (hydraulic, electrohydraulic ...).

Dynamic offsets: dynamic compensation transfer function (transient staticism, series compensator, ...). The range of each parameter and its current value must be specified.

The turbine-speed regulator block scheme and the corresponding values of the parameters that are represented in the schemas. This information will be provided as follows:

Unifilar installation protection scheme In both cases, a validation report on the suitability of the model to represent the turbine-speed regulator must be accompanied, in accordance with the conditions set out in the document to the effect developed by the OS.

1.4.2.1.2.4 Data for each additional generator for hydraulic power stations of more than 10 MW.

Turbine type.

Rated power in turbination (MW).

nominal flow (m3/s).

Net nominal jump (m).

Net technical minimum, that is, in central bars (MW).

Maximum turbination flow (m3/s).

Minimum flow rate (m3/s).

Maximum gross jump (m).

Minimum gross jump (m).

Maximum net jump (m).

Minimum net jump (m).

Losses in flow-based pipelines: Perdconduccio= f (Q2).

Throughput curves based on flow rate and net jump (alternative: power tables for different net jumps and different flow rates for each net jump).

For reversible or pumping groups:

Type of pump.

Rated power.

Nominal speed (rpm).

Nominal effective height (m).

Nominal Pump Flow (m3/s).

Maximum pump flow (m3/s).

Minimum pumping flow (m3/s).

Loss in aspiration and drive based on flow rate: Perdpipeline= f (Q2).

Performance curves based on the pumped flow and the manometric height (alternative: power tables for different manometric heights and different flow rates for each manometric height).

1.4.2.1.3 Additional data in the case of connection to the transport network.

Installation data at the point of connection to the network.

Physical diagram (general scheme at site) of the link installation.

Single-line chart of detail with all the components of the link installation from the different generation units to the point of connection to the network.

General configuration of the installation, indicating in its case characteristics of coupling between elements (e.g. gas turbines, steam turbines and alternators), as well as modularity and operating flexibility.

For generations: See consumer installations connected to the transport network.

Report with maximum guaranteed harmonic distortion content, only in case there are wave control processes in the installation:

Well through a forecast, as indicated in IEC 61000-3-6, of the harmonics of tension and intensity (magnitude and order of 2 to 50) and the rate of harmonic distortion,

Or to make measurements at the point of connection, of the harmonics of tension and intensity (magnitude and order of 2 to 50) and of the rate of harmonic distortion, in minimum periods of one week as indicated in IEC 61000-4-30.

Unifilar installation protection scheme.

1.4.2.2 Secondary regulation data (in the case of generation units participating in the secondary secondary regulation service).

Regulatory zone to which you belong.

Detailed information of the connection of the regulatory system with the AGC: characteristics of the signal signal, signal processing, limits, ...

Maximum and minimum active power of regulation in b.a. (MW) for different stable operating points, if applicable.

Limitations on upload and load drop on MW/min: adjustment range and slogan values for continuous ramp and step.

1.4.2.3 Data for tertiary programming and regulation (in non-hydraulic groups and in case of participation in the electricity production market).

Minimum programming start time:

From synchronization to minimum technical (min).

From synchronization to full load (min).

Minimum programming stop time (from full load to disconnect) (min):

Maximum up-ramp of tertiary regulation (MW in 15 min).

Top down ramp of tertiary regulation (MW in 15 min).

1.4.2.4 Data required for service replacement plans (in the case of generators or pool of generators of more than 50 MW of total power, or connected to the transport network).

SSAA power (except CCHH):

Simplified schema and description of the SSAA power process in the following assumptions:

Normal.

Boot.

Other Alternatives (Diesel/Bater/Otras) Groups.

SSAA Power Voltage.

Auxiliary services consumption in b.a. for group stop, active power (MW).

Auxiliary services consumption in b.a. for group stop, reactive power (MVAr).

Auxiliary services consumption in b.a. for startup, active power (MW). Specify different possibilities: Cold start/Hot start.

Auxiliary services consumption in b.a. for startup, reactive power (MVAr). Specify different possibilities: Cold start/Hot start.

Stand-alone boot capacity:

Own media to energize the auxiliary services needed for startup:

Battery.

Diesel Group.

Other.

Single-circle diagrams.

Autonomy time (hours).

Boot type:

By remote control.

Local operation (staff time availability will be indicated).

The minimum guaranteed operating time continued at full load during the replenishment process (minimum fuel reserves).

Possibility of performing a certain number of consecutive starts in a given time (in case of possible shots during the replacement process): number of start and stop cycles, and cycle duration.

In the case of CCHH: Minimum number of groups to operate in parallel.

Cascade startup capability for a set of groups.

Reconnect group to network (except CCHH):

Minimum cold start time (since power is received in the SSAA until ready for synchronization).

Minimum hot start time (since power is received in the SSAA until ready for synchronization).

Maximum stop time for the boot to be hot.

Ability to remain stable after a disconnect from the outside network with sudden loss of full load, only feeding its own consumption. (Yes/No. Description).

Island operating capacity. Minimum market bag that is capable of feeding the plant in island situation.

Sync conditions for coupling. Existing automatisms and adjustments (except CCHH).

Other data (except CCHH):

Characteristics of the engines and loads of ancillary services and data on protections and adjustments, if any.

Dependence on non-fuel supply infrastructures for the reorder process.

1.4.2.5 Data for group transformers.

1.4.2.5.1 Central or pool of more than 50 MW of total power not connected to the transport network.

rated power (MVA).

Nominal voltage (kV) of primary and secondary.

Connection group.

Loss due to load (kW).

Short Circuit Voltage (%).

Homopolar impedance (% on machine base).

1.4.2.5.2 Central connected to the transport network. -See transport transformers.

1.4.2.6 Data from the evacuation line or cable.

1.4.2.6.1 Central or pool of more than 50 MW of total power not connected to the transport network. -See observable network lines and cables.

1.4.2.6.2 Central attached to the transport network. -See transport lines and cables.

1.4.2.7 Data from the Protections.

1.4.2.7.1 Power stations less than or equal to 50 MW that are not connected to the transport network.

Compliance with the General Protection Criteria (which are included in the procedure for establishing the General Protection Criteria) against internal disturbances to the plant (yes/no). Indicate particularities, if any.

Minimum frequency protection: settings and compliance with the procedure that the Safety Plans are set for.

Overfrequency protection. Adjustments.

Automatic Replenishment Devices: Confirm that they do not exist or are disabled.

In case the critical time in the connection node to the network is less than 1 second, indicate:

Short-circuit protection scheme in the network-main transformer stretch.

Compliance with the General Protection Criteria.

1.4.2.7.2 Central over 50 MW or connected to the transport network.

Compliance with the General Protection Criteria (which are included in the procedure for establishing the General Protection Criteria) against internal disturbances to the plant (yes/no). Indicate particularities, if any.

Minimum frequency protection: settings and compliance with the procedure that the Safety Plans are set for.

Overfrequency protection. Adjustments.

Automatic Replenishment Devices: Confirm that they do not exist or are disabled.

In case the critical time in the connection node to the network is less than 1 second, indicate:

Short-circuit protection scheme in the network-main transformer stretch.

Compliance with the General Protection Criteria.

Minimum Voltage Relays: Settings.

Shot by Overspeed. Firing value.

1.4.2.7.3 Additional data in the case of power stations connected to the transport network.

1.4.2.7.3.1 Central Protections.

Network short-circuit support protection: indicate relay type (s), adjustment criteria and values, and coordination status (SI/NO) with network protections.

Overvoltage relay: settings.

Sync conditions for coupling. Automatisms and adjustments.

1.4.2.7.3.2 Protections associated with the link installation.

Unifilar installation protection scheme Teleshooting against network contingencies.

Teleshooting capacity (SI/NO).

The tele-firing time since the signal is received (also indicate switch opening times).

Teleshooting logic and switches or selectors that includes.

1.4.2.8 Main data for voltage control equipment.

Brief description of the voltage regulator-excitation, which will include the name and type of the regulator.

Block scheme, and the corresponding values of the parameters that are represented in the schemas, of the voltage regulators-excitepess and of the power stabilizer system (PSS), if they have this device. This information will be provided as follows:

Through a model included in the list of dynamic models supported by the OS, and that will be provided by the OS itself,

Or through a model not included in the above list provided that it meets the characteristics and conditions set out in document to the effect elaborated by the OS.

In both cases it must be accompanied by a validation report on the suitability of the model to represent the voltage regulator and the power stabiliser system (PSS), in accordance with the conditions set out in the document to the effect developed by the OS.

1.4.2.9 Supplementary voltage control service in case of transport network connection.

Indicate the option to which you are hosting: operation procedure 7.4 describing the Tension Control Complementary Service (SI/NO), Royal Decree 661/2007 (SI/NO), others (specify).

In the event that you have received the Operation 7.4 procedure, explicit declaration of compliance with the mandatory requirements set forth in that procedure (SI/NO), or defaults, if any, and their justification.

In the case of generating groups and reversible groups that have the capacity to function as synchronous compensators, the technical operating requirements shall be indicated, and the time required for their entry into operation.

The possibility, if any, of telematic the groups must be indicated so that the excitation slogan and/or the takes of the group's output transformer can be modified from the generation office of the titular subject or group representative, or from the appropriate control center.

1.4.3 Wind Parks.

1.4.3.1 Features of each park.

Name of the park.

Geographical location (requests for access to the transport network or distribution network with influence on the transport network): plans (minimum detail of particular situation E 1:50,000 and general situation E 1:200,000) and significant distances (to lines and knots of connection to the network).

Unifilar diagram with all the components of the network link installation (requests for access to the transport network or for voltage distribution networks exceeding 100 kV with influence on the transport network).

Owner Company:

Name.

NIF/CIF.

Address.

Identification number in the RAIPEE.

Special Regime Grant Date.

On or off date (forecast, if any).

Park address: municipality, postal code and province.

UTM Coordinates of the Park Polygonal.

Distributor Company.

Installed power: apparent gross (MVA) and net active (MW). The apparent power must include all of the park's reactive compensation.

Substation/network connection park (Name, kV).

Availability of primary regulation or speed regulation (SI/NO). If yes, please indicate:

Regulator sensitivity (mHz). It must not be greater than 10 mHz.

Regulator voluntary dead band (mHz): confirm that the adjusted value is zero.

In case of no primary regulation of your own, provide documentation that accredits the service delivery by another generating unit, indicating:

Unit that provides the service.

Insensitivity confirmation not greater than 10 mHz.

Null voluntary dead-band commit.

Planned operation of the park:

Hours of use (at full power) referred to on an annual and seasonal basis.

Active power curve depending on wind speed, including indication of maximum wind speeds for which wind turbines fail to provide power.

Compliance with voltage gaps (yes/no) response requirements.

Data for each wind turbine model:

Number of wind turbines of the same model.

Manufacturer and model.

Technology: Squirrel cage induction or asynchronous machine, variable-slip induction or asynchronous machine, doubly-fed induction or asynchronous machine, wind turbines with total power conversion (full converter). In case of other technologies not indicated, provide brief description.

Active power installed of each wind turbine (kW).

Apparent installed power of each wind turbine (kVA) including, if applicable, its internal reactive compensation.

A reactive power curve depending on the active power, considering, where appropriate, the internal reactive compensation of the wind turbine.

A model of the wind farm will be provided, which should describe the dynamic behavior of the installation from the point of view of the electrical system to which it is connected, in the face of any disturbance in it. This information will be provided as follows:

Through a model included in the list of dynamic models supported by the OS, and that will be provided by the OS itself,

Or through a model not included in the above list provided that it meets the characteristics and conditions set out in document to the effect elaborated by the OS.

In both cases it must be accompanied by a validation report on the suitability of the model to represent the voltage regulator and the power stabiliser system (PSS), in accordance with the conditions set out in the document to the effect developed by the OS.

Reactive compensation in wind turbine bornas excluding, if applicable, internal compensation:

Static compensation and reactive power dynamics (nominal values in MVAr).

Possibility of regulation.

Reactive compensation in park borns excluded, if any, associated with each wind turbine.

Static compensation and/or total reactive power dynamics (nominal value in MVAr).

Possibility of regulation.

Condenser Batteries (yes/no):

Total Power (MVAr).

Number of steps.

Type of control of the steps.

Power electronics-based continuous compensation or regulation systems (FACTS) (yes/no).

Total Power Installed (MVAr).

1.4.3.2 Network connection transformer data.

Company or proprietary companies:

Name.

NIF/CIF.

Address.

rated power (MVA).

Nominal voltage (kV) of primary and secondary.

Connection group.

Loss due to load (kW).

Short Circuit Voltage (%).

Homopolar impedance (% on machine base).

1.4.3.3 Network connection cable or line data. -See observable network lines and cables.

1.4.3.4 Data from the Protections.

1.4.3.4.1 Park Protections.

Compliance with the General Protection Criteria (which are included in the procedure for establishing the General Protection Criteria) in the face of internal disturbances to the park (yes/no). Indicate particularities, if any.

Minimum voltage relay: indicate phases in which measures and adjustments.

Overvoltage relay: settings.

Minimum frequency protection: settings and compliance with the procedure that the Safety Plans are set for.

Overfrequency protection. Adjustments.

Automatic Replenishment Devices: Confirm that they do not exist or are disabled.

1.4.3.4.2 Protections associated with wind turbines.

Minimum voltage relay: indicate phases in which measures and adjustments.

Overvoltage relay: settings.

Minimum frequency protection: settings and compliance with the procedure that the Safety Plans are set for.

Overfrequency protection. Adjustments.

Automatic Replenishment Devices: Confirm that they do not exist or are disabled.

Shot by Overspeed. Firing value.

1.4.3.4.3 Protections associated with the link installation.

Minimum voltage relay: settings.

In case the critical time in the connection node to the network is less than 1 second, indicate:

Short-circuit protection scheme in the network-main transformer stretch.

Compliance with the General Protection Criteria.

1.4.3.5 Additional data in the case of parks connected to the transport network.

1.4.3.5.1 Characteristics of each park.

Physical diagram (general scheme at site) of the link installation.

One-to-one detail diagram of power equipment from the different generation units to the point of connection to the network.

Short-circuit intensity contributed by the park to a short circuit at the point of connection to the network.

Report with the maximum guaranteed harmonic distortion content:

Well through a park-level forecast, as indicated in IEC 61000-3-6, of the harmonics of tension and intensity (magnitude and order of 2 to 50) and the rate of harmonic distortion,

Or perform park-level measurements of the voltage and intensity harmonics (magnitude and order of 2 to 50) and the harmonic distortion rate, at minimum periods of one week as indicated in IEC 61000-4-30.

Voltage level (kV) of the internal network of connection of the generators.

Unifilar park protection scheme and link installation.

1.4.3.5.2 Supplementary voltage control service.

Indicate the option to which you are hosting: operation procedure 7.4 describing the Tension Control Complementary Service (SI/NO), Royal Decree 661/2007 (SI/NO), others (specify).

In the event that you have received Operation 7.4 Procedure, an explicit declaration of compliance with the mandatory requirements set forth in that procedure (SI/NO), or defaults, if any, and your justification.

The possibility, if any, of telemandar groups should be indicated so that the output of the group's output transformer can be modified from the generation office of the holder or representative of the group, or from the corresponding control center.

1.4.3.5.3 Park transformer data (if this is the network connection transformer see point 1.4.3.5.5).

rated power (MVA).

Nominal voltage (kV) of primary and secondary.

Connection group.

Loss due to load (kW).

Short Circuit Voltage (%).

Homopolar impedance (% on machine base).

1.4.3.5.4 Data from the line or cable for the evacuation of each park (if this is the line or cable connection to the transport network see paragraph 1.4.3.5.6). -See observable lines and network cables.

1.4.3.5.5 Network connection transformer data. -Transport transformers.

1.4.3.5.6 Data from the evacuation line or cable (if any). -See transport lines and cables.

1.4.3.5.7 Data from the Protections.

1.4.3.5.7.1 Park Protections.

Sync conditions for coupling. Automatisms and adjustments.

1.4.3.5.7.2 Protections associated with the link installation.

Short-circuit protection scheme in the main network-transformer section. Compliance with the General Protection Criteria.

Network short-circuit support protection: indicate relay type (s), adjustment criteria and values, and coordination status (SI/NO) with network protections.

1.4.3.5.7.3 Telefiring against network contingencies.

Teleshooting capacity (SI/NO).

The tele-firing time since the signal is received (also indicate switch opening times).

Teleshooting logic and switches or selectors that includes.

2. Transport network.

2.1 Substations.

The name of the substation.

Address: municipality, postal code, and province.

On or off date (forecast, if any).

2.2 Parks.

The name of the substation.

Voltage (kV).

UTM Park Coordinates (give a reference point).

Configuration.

Owner of each position.

Owner of each bar.

Maximum allowable short circuit intensity of the various elements of the park.

Short circuit breaker power of switches.

Uniform protection and measurement schemes.

On or off date (forecast, if any).

Protections:

Compliance with the General Protection Criteria (in accordance with the procedure for establishing the General Protection Criteria). Indicate particularities, if any.

Short-circuit protection scheme. Critical time contemplated.

Protection from external shorthand support: indicate relay type (s), adjustment criteria and values, and coordination status (SI/NO) with the protections of other elements.

Unifilar protection and measurement scheme.

Minimal voltage relays: trigger logic and switches on which they operate.

2.3 Lines and cables.

Denomination of the line.

Line ends of the line.

Number of circuits and length in km.

Owner or set of owners and participation in your case.

On or off date (forecast, if any).

Nominal operating voltage and maximum service of each circuit (and projected in case of variation) for each circuit or tranches thereof with homogeneous characteristics.

Direct Sequence Resistance (P&C).

Direct Sequence Reactance (P&C).

Direct Sequence Sensitivity (µ S).

Homopolar Sequence Resistance (P&C).

Homopolar Sequence Reactance (P&C).

Homopolar Sequence (µ S) Sensitivity.

Additional data for transport network lines and cables only, as such:

Seasonal values (summer, fall, winter, spring) of:

Nominal line transport capacity (MVA).

limiting element.

Permanent Thermal Conductor Boundary (MVA).

Maximum driver operating temperature (0C).

Length in shared supports, if any (in a same ditch or gallery, if isolated cables are treated).

Configuration of the line.

Driver: Name/material/total section (mm2).

Earth Cables: Denomination/material/total section (mm2).

Set-to-ground configuration (for isolated cables only): Type/length of sections.

Number of drivers per phase.

Protections:

Compliance with the General Protection Criteria (in accordance with the procedure for establishing the General Protection Criteria). Indicate particularities, if any.

Short-circuit protection scheme. Critical time contemplated.

Protection from external shorthand support: indicate relay type (s), adjustment criteria and values, and coordination status (SI/NO) with the protections of other elements.

Unifilar protection and measurement scheme.

Network couplers or telecouplers: existence and adjustments.

Synchronism Relays: existence and settings. Break down, if necessary, between monitoring of reengagement and voluntary closure.

Minimal voltage relays: trigger logic and switches on which they operate.

Overvoltage protection: existence and settings.

Automatic Replacement Devices: Indicate if they exist and describe their behavior, if any.

Reengagement:

Relatch position under normal operating conditions (not active/mono/mono + tri/tri).

Extreme that throws tension in the three-phase reengagement.

Synchronism monitoring in triphasic reengagement (SI/NO).

Teleshooting:

Telefiring on voluntary opening (SI/NO).

Switch opening shot (SI/NO).

2.4 Transformers. -Transformers that feed loads and those connected to non-observable networks are dealt with under the heading "Consumer installations".

Substation and park name of the highest voltage level.

Order number.

Geographical location (requests for access to the transport network or distribution network with influence on the transport network): plans (minimum detail of particular situation E 1:50,000 and general situation E 1:200,000) and significant distances (to lines and knots of connection to the network).

Unifilar diagram with all components of the network-link installation (requests for access to the transport network or for voltage distribution networks greater than 100kV with influence on the transport network).

Physical diagram (general scheme at site) of the link installation.

Unifilar detail diagram of the power equipment of the network link installation.

Owner or set of owners and participation in your case.

On or off date (forecast, if any).

Type of transformer: configuration (triphasic or bank), autotransformer/transformer, magnetic circuit (n. of columns).

Nominal power of each winding (MVA).

Cooling type.

Nominal voltage of each winding (kV).

Maximum Service Voltage (kV).

Connection group.

Type of regulation in each winding: load or vacuum, automatic regulation (SI/NO) and collapse before collapse (SI/NO).

Number of shots in each winding and extension of takes (%). Number of the main shot (corresponding to the nominal voltage of the transformer), the usual intake (vacuum regulation) and the maximum intake. For generation transformers, in addition, numbers of the usual take (vacuum changer) or of the most frequent (shift-in-load-changer).

The primary and secondary transformation relationship for each of the possible transformer or autotransformer takes.

Transformer losses:

Losses due to load between each winding pair (kW).

Empty (kW) losses.

Losses in auxiliary equipment (kW).

Short circuit voltage between each pair of windings in the main, maximum and minimum takes in their case (%). Main takeaway in generation transformers.

Homopolare impedances between each winding and its neutral borne in the main, maximum and minimum takes in its case (% on a machine basis). Main takeaway in generation transformers.

Additional data for transformers of the transport network and of the observable network, as such:

Protections:

Compliance with the General Protection Criteria (in accordance with the procedure for establishing the General Protection Criteria). Indicate particularities, if any.

Short-circuit protection scheme. Critical time contemplated.

Protection from external shorthand support: indicate relay type (s), adjustment criteria and values, and coordination status (SI/NO) with the protections of other elements.

Unifilar protection and measurement scheme.

Minimal voltage relays: trigger logic and switches on which they operate.

Overvoltage protection: existence and settings.

For observable network transformers:

Explicit declaration of compliance with the mandatory voltage control requirements set out in the operation procedure 7.4 describing the Complementary Tension Control Service or non-compliances, in their case, and their justification.

2.5 Active or reactive power control elements.

The name of the substation and park in which it is located.

Type (Reactance or Capacitor or Dynamics; information will be replicated in case of elements with inductive and capacitive compensation possibilities).

Order number.

Nominal voltage (kV).

rated power (MVAr).

Connection Voltage (kV).

Situation (transformer bars or tertiary).

Owner.

Loss in iron (kW).

Copper losses (kW).

Additional total included losses (kW).

Connection type.

Number of steps.

For each step:

No. of blocks.

Nominal power of each block (MVAr).

On or off date (forecast, if any).

In the case of FACTS devices (Flexible AC transmission system): the characteristics of the transformer of connection to the network, nominal voltage of the compensating equipment, characteristic V/I of the compensation system, and scheme of blocks with the corresponding values of the parameters that are represented in the schema. This information will be provided as follows:

Through a model included in the list of dynamic models supported by the OS, and that will be provided by the OS itself,

Or through a model not included in the above list provided that it meets the characteristics and conditions set out in document to the effect elaborated by the OS.

In both cases, a validation report of the suitability of the model to represent the FACTS device must be accompanied, in accordance with the conditions set out in the document to the effect developed by the OS.

In the case of active power control elements, the associated data will be provided based on the corresponding configuration.

Protections:

Compliance with the General Protection Criteria (in accordance with the procedure for establishing the General Protection Criteria). Indicate particularities, if any.

Short-circuit protection scheme. Critical time contemplated.

Protection from external shorthand support: indicate relay type (s), adjustment criteria and values, and coordination status (SI/NO) with the protections of other elements.

Unifilar protection and measurement scheme.

Minimal voltage relays: trigger logic and switches on which they operate.

Overvoltage protection: existence and settings.

Automatic Replacement Devices: Indicate if they exist and describe their behavior, if any.

3. Consumer installations connected to the transport network.

As far as processors are concerned, the present epigraph is applicable to those who feed loads and those connected to unobservable networks. The observable network transformers are dealt with in the Network Observable chapter.

Naming the installation.

Order number.

Geographical location (requests for access to the transport network or distribution network with influence on the transport network): plans (minimum detail of particular situation E 1:50,000 and general situation E 1:200,000) and significant distances (to lines and knots of connection to the network).

Unifilar diagram with all the components of the network link installation (requests for access to the transport network or for voltage distribution networks exceeding 100 kV with influence on the transport network).

Unifilar detail diagram of the power equipment of the network link installation.

Owner.

Home of the installation. Municipality, postal code and province.

On or off date (forecast, if any).

Load type (distribution network, auxiliary services, consumer).

Substation and network connection park (Name, kV).

General installation configuration, modularity, and operating flexibility.

Estimated unavailability rates for maintenance and other causes (annual and seasonal indices if applicable).

Planned operating system. Consumption forecast (MW, MVAr) at the point of network connection in significant time and seasonal situations, as well as annual estimated energy.

Network Connection Transformer:

Transform type: configuration (triphasic or bank), autotransformer /transformer, magnetic circuit (n. of columns).

Nominal power of each winding (MVA).

Nominal and maximum service voltage of each winding (kV).

Connection group.

Loss due to load (kW).

Short Circuit Voltage (%).

Homopolar impedance (% on machine base).

Main load composition characteristics (if applicable):

Proportion of induction engines (% on total load).

Of the rest of the load that does not correspond to induction engines:

Comparable ratio to constant power load (%).

Equivalent to constant impedance load ratio (% on).

Equivalent to constant intensity load ratio (%).

Tension control:

explicit declaration of compliance with the mandatory stress control requirements laid down in the procedure for describing the Supplementary Tension Control Service or non-compliances, if any, and justification.

Additional information for arc furnaces in alternating current:

High Voltage (kV).

Media Voltage (kV).

Low Voltage (kV).

furnace power (MVA).

Reactive compensation: type, rated power (MVAr), and connection sweep.

Short circuit and power impedance of MT-BT transformers.

The impedance of the serial reactance, if any.

The impedance of the low voltage cables, the electrode, and any additional ones that may exist from the point of connection to the network to the electrode.

Cos φ of the previous impedances.

Additional information for arc furnaces in continuous stream:

High Voltage (kV).

Media Voltage (kV).

Low Voltage (kV).

rectification power (MW).

Number of pulses.

Reactive compensation: type, rated power (MVAr), and connection sweep.

Short circuit and power impedance of MT-BT transformers.

The impedance of the low voltage cables, the electrode, and any additional ones that may exist from the point of connection to the network to the electrode.

Cos φ of the impedance of low voltage cables.

Harmonic filters: Order of harmonics to which each filter and unit power (MVAr) is tuned.

Additional information for TAV and unbalanced loads:

Nominal voltage (kV).

Nominal power (MVA) and phases between which it loads.

Characteristics of the imbalance compensation team, if any.

Additional information for induction engines of more than 10 MW or loads having special dynamic characteristics, in the face of the voltage or frequency, not indicated above, if they are not characterised by the main characteristics of the load composition defined above and if the OS considers it relevant:

A model will be provided that should describe the dynamic behavior of the installation from the point of view of the electrical system to which it connects, to any disturbance in it. This information will be provided as follows:

Through a model included in the list of dynamic models supported by the OS, and that will be provided by the OS itself,

Or through a model not included in the above list provided that it meets the characteristics and conditions set out in document to the effect elaborated by the OS.

In both cases, a validation report of the suitability of the model to represent this type of load should be accompanied, in accordance with the conditions set out in the document to the effect developed by the OS.

Line or cable connection to the RdT (if applicable):

Number of circuits and length in km.

Owner or set of owners and participation in your case.

On or off date (forecast, if any).

Nominal operating voltage and maximum service of each circuit (and projected in case of variation) for each circuit or tranches thereof with homogeneous characteristics.

Direct Sequence Resistance (P&C).

Direct Sequence Reactance (P&C).

Direct Sequence Sensitivity (µ S).

Homopolar Sequence Resistance (P&C).

Homopolar Sequence Reactance (P&C).

Homopolar Sequence (µ S) Sensitivity.

Protections:

Compliance with the General Protection Criteria (in accordance with the procedure for establishing the General Protection Criteria). Indicate particularities, if any.

Short-circuit protection scheme. Critical time contemplated.

Protection from external shorthand support: indicate relay type (s), adjustment criteria and values, and coordination status (SI/NO) with the protections of other elements.

Unifilar protection and measurement scheme.

Minimal voltage relays: trigger logic and switches on which they operate.

Overvoltage protection: existence and settings.

Frequency relay features and tuning:

Frequency: adjustment range, stagger, and adjustment value (Hz).

Timing: Adjustment Range and Adjustment Value (s).

Existence of reorder mechanism (SI/NO). If yes, confirm your non-enablement.

Minimum and maximum loads disconnected by the relay (MW).

Identification of the switch on which the relay is acting.

Automatic reorder devices not associated with the frequency relay: Indicate if they exist and describe their behavior, if any.

4. Observable network.

4.1 Substations.

The name of the substation.

Address: municipality, postal code, and province.

On or off date (forecast, if any).

4.2 Parks.

The name of the substation.

Voltage (kV).

Configuration. Single-line detail.

Owner of each position.

Owner of each bar.

On or off date (forecast, if any).

4.3 Lines and cables.

Line name.

Line ends of the line.

Number of circuit and length in km.

Owner or set of owners and participation in your case.

On or off date (forecast, if any).

Direct Sequence Resistance (P&C).

Direct Sequence Reactance (P&C).

Direct Sequence Sensitivity (µ S).

Homopolar Sequence Resistance (P&C).

Homopolar Sequence Reactance (P&C).

Homopolar Sequence (µ S) Sensitivity.

Additional data in case of lines and cables of the observable network, as such:

Nominal line transport capacity (MVA), seasonal values (summer, autumn, winter, spring).

4.4 Transformers.

Transformers connected to the transport network are dealt with in the "Transport Network" chapter.

Block scheme, and the corresponding values of the parameters that are represented in the schemes, of the voltage regulators-excitation and of the power stabilizer system (PSS), if they have this device. This information will be provided as follows:

Through a model included in the list of dynamic models supported by the OS, and that will be provided by the OS itself,

Or through a model not included in the above list provided that it meets the characteristics and conditions set out in document to the effect elaborated by the OS.

In both cases, it must be accompanied by a validation report on the suitability of the model to represent the voltage regulator and the power stabiliser system (PSS), in accordance with the conditions set out in the document to the effect developed by the OS.

This item is applicable to elements directly connected to knots of the observable network.

The name of the substation and park in which it is located.

Type (Reactance or Capacitor or Static).

Order number.

Owner.

On-or-off date (forecast if applicable).

Nominal voltage (kV).

rated power (MVAr).

ANNEX II

Information to be sent to the OS in real time

Transport network and observable network.

Switches.

Senalizations.

Switch position.

Sectors.

Senalizations.

Position of the dryers.

Lines.

Measures.

Active Power (MW).

reactive power (MVAr).

Transformers (includes transport, generation and consumption), reactances and capacitors.

Senalizations.

Switch position.

Position of the dryers.

Automatic voltage control (transformers only).

Measures.

The primary active power of transformer (MW).

Transformer primary reactive power (MVAr).

Transformer secondary active power (MW).

Transformer Secondary Reactive Power (MVAr).

Transformer tertiary active power (MW).

Transformer tertiary reactive power (MVAr).

Take the regulator into load (transformers only).

Empty regulator position (if it exists and only transformers).

Reactive Power in Reactances (MVAr).

Coupling of bars.

Senalizations.

Switch position.

Position of the dryers.

Measures.

Active Power (MW).

reactive power (MVAr).

Bars.

Measures.

Tension per bar section (kV).

Frequency metric on selected selected bars (Hz).

Thermal groups and hydraulic groups with regulatory capacity.

Senalizations.

Group throttling local/remote state.

Type of regulation, control/unchecked.

Thermal groups.

Senalizations.

Position of the group switches.

Measures.

Active power on the machine transformer (MW).

High-reactive power of the machine transformer (MVAr).

Low active power of the machine transformer (MW).

Low reactive power of the machine transformer (MVAr).

Generation Voltage.

Hydraulic groups.

Measures.

Active power on the machine transformer (MW).

High-reactive power of the machine transformer (MVAr).

Pure pumping groups.

Measures.

Active power on the machine transformer (MW).

High-reactive power of the machine transformer (MVAr).

Reservoirs of reservoirs.

Wind groups.

Measures.

High-powered active power by wind farm (MW).

High-reactive power by wind farm (MVAr).

Central Bar Voltage Measurement (kV).

Park connection status with the distribution or transport network.

Temperature (ºC).

Wind speed (intensity and direction) (m/s and sexagesimal degrees).

Non-Wind Special Regime.

Measures.

Active power produced by each of the generation units if within the installation there are different consumption to the auxiliary services of the generation units or some of the units has a power equal to or greater than 10 MW and net value of the active power exchanged with the network (MW).

Reactive power produced/absorbed by each of the generation units if within the facility there are different consumptions to the auxiliary services of the generation units or some of the units a power equal to or greater than 10 MW and a net value of the reactive power exchanged with the network (MVAr).

Central Bar Voltage Measurement (kV).

Synchronous compensators.

Senalizations.

Connection status.

Analog measures.

reactive power (MVAr).

Voltage (kV).

ANNEX III

Incident report

The contents to be included in the report on an incident are those that are applicable to the following:

a) The date and time of the incident.

b) Transport facilities and/or electrical system elements directly involved in the incident (and not only affected by the incident), duration of loss of service (with indication of whether it is data or forecast).

c) Direct impact to final consumers, for each border point with the affected transport network: location, type and number of customers affected, demand (in MW) interrupted, energy not supplied (in MWh) and duration of the interruption (with indication of whether it is data or forecast). In addition, the details of the replacement of the service, indicating the powers and the interruption times for each stage of the replacement, shall be given as detailed as possible.

d) Affecting to generation: affected group or groups, interrupted generation (MW) and duration of disruption (with indication of whether it is data or forecast). Damage reported.

e) Description of the incident (chronology of events, action of protection systems and automatisms, ...).

P. O. 14.4 Recovery rights and payment obligations for system adjustment services

1. The purpose of this procedure is to determine the payment entitlements and the payment obligations arising from the adjustment services of the system for the purposes of the winding-up process, as laid down in the procedure of Operation 14.1 and in the Operation Procedures relating to such services.

System tuning services include:

(a) The resolution of supply security restrictions as set out in P.O. 3.10.

b) The resolution of technical restrictions of the PBF, the intraday and real-time market established in the Operation Procedure 3.2.

c) The generation-consumption deviation resolution set forth in Operation Procedure 3.3.

d) The secondary regulatory services provided in the Operation Procedure 7.2.

e) Complementary tertiary regulation services established in Operation Procedure 7.3.

f) The deviations between the measurement in central bars and the program.

2. Scope. -This procedure is applicable to the System Operator and the Electrical Power Production Market Subjects.

3. General criteria.

3.1 Sign Criteria. The sign criterion adopted in the formulas of this procedure is as follows:

a) Energy production and import have a positive sign. Energy consumption and export have a negative sign.

b) The energy to go up has a positive sign. Energy is defined to be raised as increases in energy production or import and decreases in energy consumption or export.

c) The energy to be lowered has a negative sign. Energy is defined to be lowered as decreases in energy production or import and increases in energy consumption or export.

d) The receivables have a positive sign. Payment obligations have a negative sign.

3.2 Measures. -The measures referred to in the texts and formulas of this operating procedure will be understood as expressed in the following units:

(a) The energy quantities shall be understood as expressed in MWh with the number of decimal places in which the energy allocation or measurement is carried out in each case and up to a maximum of three decimal places.

(b) The power quantities shall be understood to be expressed in MW with the number of decimal places where the allocation or measurement of power is carried out in each case and up to a maximum of three decimal places.

(c) Energy prices shall be understood as expressed in euro per MWh with the accuracy with which they are determined on each market.

(d) Power prices shall be understood as expressed in euro per MW with the accuracy with which they are determined on each market.

e) The percentages will be understood already divided by 100.

(f) Payment entitlements and payment obligations shall be understood as expressed in euro with two decimal places, where necessary, the rounding necessary.

3.3 Formulas. -The terms of the formulas of this operating procedure will be understood as referring to values of one hour, except express mention in another sense.

The term "PMD" in the formulas of this Operation Procedure means Daily Market Price.

In the distribution formulas, the minimum error rounding method will be applied to obtain rounded results that add up the amount to be distributed.

3.4 Terms. -In this procedure the term consumer direct refers to Direct Consumer in Market.

Marketing programming unit refers to the programming unit of a marketer for energy purchase for supply to its national customers on the peninsula.

Direct Consumer Programming Unit refers to the direct consumer programming unit for power purchase for consumption on the peninsula.

Acquisition unit for demand refers, in general, to the programming units of the two preceding paragraphs.

4. Restrictions for security of supply and for technical restrictions of the PBF.

4.1 PBF modifications by security of supply and by security criteria.

4.1.1 Technical restrictions on PBF to be moved up in phase 1 to sales units.

4.1.1.1 Simple offer.-The allocation of energy to be raised for the resolution of technical restrictions of the PBF with the use of the simple offer, because the complex offer will not be applicable, will give rise to a right of recovery of the unit u, for each block of energy b allocated, which is calculated according to the following formula:

DCERPVPVOSu, b = ERPVPVOSu, b × POPPVPVOSu, b

where:

ERPVPVOSu, b = Energy to be uploaded from the offer lock simplex the unit or allocated in phase 1.

POPPVPVOSu, b = Offerited price for simple offer for the u block b.

4.1.1.2 Complex Offering.-The allocation of energy to be raised for the resolution of technical restrictions of the PBF with the use of the complex offer will result in a right of collection of the unit or calculated according to the formula next:

DCERPVPVOCu = ERPVPVOCu × POPPVPVDIAu

where:

ERPVPVOCu = Energy to be uploaded from the unit or, in application of the complex offering.

POPVPVDIAu = Applicable price for all hours of the day resulting from the application of the complex offering and obtained as follows:

POPVPVDIAu = minimum (IMPPVPu, IMPPHFu)/ h ERPVPVOCu, h

Being IMPPVPu and IMPPHFu the unit's daily income or resulting from the application of the complex offer to the program by constraints on the PVP and PHF respectively, as set out continuation:

IMPPVPu = NAFu, pvp × PAFu + NACu, pvp × PACu + NHESu, pvp × PHCu + ERPVPu × PECu

where:

NAFu, pvp = Number of cold daily starts scheduled in PVP.

PAFu = Cold start price in complex offering.

NACu, pvp = Number of hot daily starts scheduled in PVP.

PACu = Hot start price in the complex offering.

NHESu, pvp = Number of hours daily with power to go up for resolution of technical constraints of the PBF with use of the complex offering.

PHCu = Price per hour in the complex offering.

ERPVPu = Daily energy to be uploaded for the resolution of technical constraints of the PBF with the use of the complex offering.

PECu = Energy price in the complex offering.

It is considered that there is a scheduled start in PVP at hour h when in that hour there is no power allocated by PBF, there is power allocated by technical constraints to go up in phase 1 and in the previous hour there is no power allocated neither in PBF nor by technical restrictions in phase 1 to upload. If the block of previous and contiguous hours h with PBF zero program plus phase 1 to upload is equal to or less than four, the scheduled start will be hot. Otherwise it will be cold.

IMPPHFu = NAFu, phf × PAFu + NACu, phf × PACu + NHRu, phf × PHCu + PHFu, phf × PECu -IMDCBMI

where:

NAFu, phf = Number of cold daily starts scheduled in PHF.

PAFu = Cold start price in complex offering.

NACu, phf = Number of hot daily starts scheduled in PHF.

PACu = Hot start price in the complex offering.

NHRu, phf = Number of hours per day with PHF greater than zero.

PHCu = Price per hour in the complex offering.

PHFu, phf = Daily PHF Energy on the day.

PECu = Energy price in the complex offering.

IMDCBMIu = Sum of daily revenue in the first three hours on the daily market and bilateral contracts, calculated by marginal price valuation of the daily energy market of the PBF, and the daily balance of the Intra-day market sessions, phase 2 PBF restrictions and intra-day market restrictions.

If IMDCBMI < 0 then IMDCBMI = 0.

If IMPPHFu < 0, then IMPPHFu = 0.

A scheduled boot is considered to exist in PHF at hour h when in that hour there is no power allocated by PBF, there is power allocated by technical constraints in phase 1 to go up and in some previous hour there is no power assigned in PHF. If the block of previous and contiguous hours h with PHF zero program is equal to or less than four the scheduled boot will be hot. Otherwise it will be cold.

4.1.1.3 No offer or inadequacy of the existing offer.-The allocation of energy to be raised for the resolution of technical restrictions of the PBF by exceptional mechanism of resolution will result in a right of recovery of the unit or which is calculated according to the following formula:

DCERPVPVMERu = ERPVPVMERu × 1,15 × PMD

where:

ERPVPVMERu = Energy redeployed to upload by technical constraints of the PBF by exceptional resolution mechanism of the unit of sale or.

4.1.2 Technical restrictions on PBF to be put up in phase 1 to units of purchase and export consumption.

4.1.2.1 Daily market transaction.-The allocation of energy to be raised for the resolution of technical restrictions of the PBF to units of purchase and export consumption corresponding to the transactions of the the daily market shall be deemed to be a correction of the entry into account on the Spanish production market equivalent to a right of recovery of the unit or, which is calculated according to the following formula:

DCERPVPCu = ERPVPCu × PMD

where:

ERPVPCu = Energy to be uploaded for resolution of technical constraints of the purchase unit's PBF.

4.1.2.2 Transaction associated with the execution of a bilateral contract with physical delivery. -The allocation of energy to be raised for the resolution of technical restrictions of the PBF to units of purchase of pumping and of consumption export of the transaction associated with the execution of a bilateral contract with physical delivery shall not result in any economic settlement.

4.1.3 Technical restrictions on PBF to be lowered in phase 1 to sales units.

4.1.3.1 Daily market transaction.-The allocation of energy to be lowered for the resolution of technical restrictions of the PBF to sales units corresponding to daily market transactions shall be considered as a rectification of the entry into account on the Spanish production market equivalent to a payment obligation for the unit or, which is calculated according to the following formula:

OPERPVPVu = ERPVPVBu × PMD

where:

ERPVPVBu = Energy to be downloaded for the resolution of technical constraints of the sales unit's PBF.

4.1.3.2 Transaction associated with the execution of a bilateral contract with physical delivery in which the acquisition unit corresponds to a non-pumping national consumption. -The allocation of energy to be lowered for the resolution of technical restrictions of the PBF to sales units corresponding to transactions associated with the execution of a bilateral contract with physical delivery in which the unit of acquisition corresponds to a domestic consumption, excluding pumping, shall give rise to a payment obligation calculated according to the following formula:

OPERPVPCBNu, cb = ERPVPCBNu, cb × PMD

where:

ERPVPCBNu, cb = Energy to be downloaded for resolution of technical constraints of the unit's PBF or the bilateral cb contract.

4.1.3.3 Transaction associated with the execution of a bilateral contract with physical delivery in which the unit of acquisition corresponds to a pumping consumption or an export. -The allocation of energy to be lowered for the resolution of technical restrictions of the PBF to sales units corresponding to transactions associated with the execution of a bilateral contract with physical delivery in which the unit of acquisition corresponds to a pumping consumption or an export shall not give rise place for economic settlement.

4.1.4 Failures of starts or assignments to move up from phase 1.-Scheduled starts will be reviewed by checking that they have actually been performed according to the measures and the specific type of boot will be checked (cold or hot), taking into account that a cold scheduled start, when revised, may become a hot start according to the measures received, but not the other way round. For this purpose, the measures of the unit shall be taken into account in the last 5 programming periods of the day preceding the day of liquidation.

If there is a reduction in the number of starts or variation of the boot type, the collection rights calculated in section 4.1.1.2 will be recalculated using the number and type of starts actually made.

In the event that at all hours of the day with power scheduled to rise in phase 1, the energy measured for the unit is equal to or greater than the security programmed in the PVP, the calculated charging rights will be maintained and reviewed according to the preceding paragraph.

In the event that the one-hour measure is less than the security programmed in the PVP, a payment obligation or a charge duty calculated according to the following formula shall be entered:

OPEINCPVPu = EINCPVPu × (PMEDPVPSu -PMD) if PMEDPVPSu> PMD

DCEINCPVPu = EINCPVPu × (PMEDPVPSu -PMD) if PMD > PMEDPVPSu

where:

EINCPVPu = Unfulfilled power to move up in phase 1 of the unit or discounting the power-driven default to be lowered by real-time constraints.

PMEDPVPSu = The weighted average price of all scheduled power to be uploaded for the resolution of technical constraints of the PBF in phase 1 of the u.

The unfulfilled power is calculated according to the following formula:

EINCPVPu = MAX [-ERPVPu, MIN (0, MEDRTR-PVP)]

where:

MEDRTR = MBC, if RTR ≥ 0 or if PVP ≤ PHF + TG.

MEDRTR = MAX (PBF, MBC) + MIN [PVP-(PHF + TG),-RTR] if RTR < 0 and PVP≥ PHF + TG.

MEDRTR: a measure used for the calculation of the power failure to move up from phase 1, in which the energy-driven default is ignored for restrictions in real time.

MBC: measured in central bars, as set out in paragraph 13.2.

TG: sum of tertiary regulation power, deviation management, and real-time constraints.

RTR: Sum of power of constraints in real time.

4.1.5 Energy withdrawn by congestion at international border. -Energy withdrawal from the Operating Base Program to the units of sale or acquisition of transactions associated with a bilateral contract with physical delivery by Congestion at international borders shall not result in any economic settlement.

4.1.6 Restrictions on supply warranty.

4.1.6.1 Energy programmed in PBF. -In the event that one of the programming units of which are required to participate in the process of the resolution of restrictions by guarantee of supply as selling units has been programmed in the PBF, and provided that the maximum production volume scheduled in the calendar year has not been reached, the unit or a charge or a payment obligation shall be allocated to the unit or a payment obligation calculated according to the following formula:

If CVRu ≤ PMD < PSGSu

DCEPBFGSu = EPBFGSu x (PSGSu -PMD)

If PSGSu < PMD OPOPPBFGSu = EPBFGSu x (PSGSu -PMD)

where:

EPBFGSu = Power programmed in the base program of operation to the unit or, being one of the required to participate in the process of solution of constraints by guarantee of supply and that does not exceed the value power of the published weekly operating plan, EPFGSu, by the system operator.

EPBFGSu = MIN (PBFu, EPFGSu).

PSGSu = The unit or unit time price, corresponding to the unit cost of generation set for each central with the decimals that, if any, are set to be normalized in euro/MWh.

CVRu = The regulated variable cost of the unit or, truncated, if any, to two decimal places in euro/MWh.

4.1.6.2 Energy programmed for the resolution of restrictions by guarantee of supply in the PBF.-The allocation of energy to be raised for solution of restrictions by guarantee of supply will give rise to a right of recovery that is calculates according to the following formula:

DCESGSu = ESGSu x PSGSu

where.

ESGSu = Power scheduled to be uploaded to the unit or in the supply warranty constraint resolution process.

PSGSu = Unit or unit time price, corresponding to the generation unit cost set for each central.

4.1.6.3 Obligation to pay for non-compliance with the production of the programmed energy by guarantee of supply. -In the case that at all times of the day with energy programmed by guarantee of supply, the energy measured for the unit is equal to or greater than the scheduled unit, the collection rights calculated in accordance with the preceding paragraph shall be maintained.

In the event that the one-hour measure is less than the one scheduled for the supply guarantee in the PVP, a payment obligation or a charging right calculated according to the following formula shall be entered:

OPEINCGSu = EINCGSu × (PSGSu -PMD) if PSGSu > PMD

DCEINCGSu = EINCGSu × (PSGSu -PMD) if PMD > PSGSu

where:

EINCGSu = Unfulfilled energy to be uploaded by unit or unit supply warranty.

EINCGSu = MIN (0, MBCu -EPPVPGSu).

PSGSu = Unit or unit time price, corresponding to the generation unit cost set for each central.

MBCu Production measured on central bars of the u.

EPPVGSu = (EPBFGSu + ESGSu)

EPBFGSu Energy programmed in the base program of operation to the unit or with payment entitlements or obligations as noted in section 4.1.6.1.

ESGSu Energy scheduled to be uploaded to the unit or in the process of resolution of supply warranty restrictions.

4.2 Reequilibrium generation-demand. -Energy assigned to lower, to obtain a balanced program in generation and demand, to units of energy sales corresponding to bilateral contracts whose demand has been reduced in the first stage of the process of resolution of technical restrictions of the PBF shall not result in any economic settlement.

The energy assigned to go up, to obtain a program balanced in generation and demand, to units of energy acquisition (consumption of pumping or, export) corresponding to bilateral contracts whose generation has been reduced in the first stage of the process of resolution of technical restrictions of the PBF, it shall not result in any economic settlement.

4.2.1 Energy programmed to move up in phase 2 technical constraints.

4.2.1.1 With simple offer presented.-The allocation of energy to be raised to solve a generation deficit and thus obtain a balanced program generation-demand will result in a right of collection of the unit or, for each block of the allocated b energy, calculated according to the following formula:

DCERECOOSSu, b = ERECOOSSu, b × POECOSu, b

where:

ERECOOSSu, b = Power of the single-offer b block of the unit or allocated in phase 2.

POECOSu, b = The price of the simple power supply to be uploaded from the block b of the u, for the process of resolution of technical constraints.

4.2.1.2 No simple offer presented.

4.2.1.2.1 Acquisition units. -Energy assigned to rise to solve a generation deficit and thus obtain a balanced program generation-demand to acquisition units that have not presented the corresponding Energy supply to be raised for the process of resolution of technical restrictions, shall give rise to a charge calculated according to the following formula:

DCERECOSu = ERECOSu × 0.85 × PMD

where:

ERECOSu = Energy to be uploaded to the unit or in phase 2, with no offer available.

4.2.1.2.2 Sales units. -Energy assigned to rise to solve a generation deficit and thus obtain a balanced program generation-demand to sales units that have not presented the corresponding simple offer of energy to be raised for the process of resolution of technical restrictions, shall give rise to a charge which is calculated according to the following formula:

DCERECOSOSu = ERECOSOSu × 0.85 × PMD

where:

ERECOSOSu = Energy assigned to upload to the unit or, with no offer presented.

When allocations are made by exceptional resolution mechanism, it will result in a charging right that is calculated according to the following formula:

DCERECOMERSu = ERECOMERSu × 1,15 × PMD

where:

ERECOMERSu = Energy assigned to upload to the unit or, with no offer available.

When all bids submitted are allocated, allocations by exceptional resolution mechanism will be made, resulting in a charging right that is calculated according to the following formula:

DCERECOMERSu = ERECOMERSu × 1,15 × PMD

where:

ERECOMERSu = Energy assigned to upload to the unit or, with no offer available.

4.2.2 Energy scheduled to be dropped in phase 2 technical constraints.

4.2.2.1 With simple offer presented.-The allocation of energy to be lowered in order to solve an excess generation and thus obtain a balanced program generation-demand will result in an obligation to pay the unit or, for each block of the allocated b energy, calculated according to the following formula:

OPERECOOSBu, b = ERECOOSBu, b × POECOBu, b

where:

ERECOOSB u, b = Energy to be lowered from the b block of the simple offering of the unit or allocated in phase 2.

POECOB u, b = Price of the power supply to be lowered from the block b of the u, for the process of resolution of technical constraints.

4.2.2.2 No offer presented.

4.2.2.2.1 Acquisition units. -Energy assigned to be lowered to solve an excess generation and thus obtain a balanced program generation-demand to units of acquisition when assigned all the offers presented, allocations by exceptional resolution mechanism shall be made, giving rise to a payment obligation calculated in accordance with the following formula:

OPERETRADEu = ERETRADE Bu × 0.85 × PMD

where:

ERETRADE Bu = Energy to be dropped in phase 2 to the unit or, no offer available.

4.2.2.2.2 Sales units. -Energy assigned to be lowered to solve an excess generation and thus obtain a balanced program generation-demand to sales units that have not submitted the corresponding energy supply To be lowered for the process of resolution of technical restrictions it shall result in a payment obligation calculated according to the following formula:

OPERECOSOBu = ERECOSOBu × 1,15 × PMD

where:

ERECOSOBu = Energy to be dropped in phase 2 to the unit of sale or, with no offer presented.

4.2.3 Energy scheduled to be lowered for resolution of the imbalances between generation and demand after the resolution of supply-guarantee restrictions.-The allocation of scheduled energy to be lowered will result in an obligation payment at the daily market price.

OPEBGSu = EBGSu x PMD

where:

EBGSu = Scheduled energy to be lowered to resolve the imbalances between generation and demand after the resolution of supply warranty restrictions. This value is negative.

4.3 Over the technical constraints of the PBF.-The cost of the technical restrictions of the PBF (SCPVP) is calculated as the sum of all the payment entitlements and payment obligations of paragraphs 4.1.1 to 4.1.4 and of the paragraphs 4.2.1 and 4.2.2.

The cost of the technical restrictions of the PBF will be borne by the units of purchase, in proportion to their measured consumption to central bars, MBCua. The production units, the units of purchase corresponding to the supply of auxiliary services of the production units and the units of purchase whose destination is the supply, are exempted from this allocation. out of the Spanish electrical system

The payment obligation of each acquisition unit for the payment of the cost of the technical restrictions of the PBF is calculated according to the following formula:

OPSCPVPua = SCPVP × MBCua /ua MBCua

4.4 Economic Balance of Supply Warranty Restrictions-The economic balance of the supply guarantee restrictions is calculated as the sum of all payment entitlements and payment obligations under paragraphs 4.1.6. and 4.2.3.

This balance shall be borne by the balance resulting from the difference between the income from the financing of the payments by capacity and the costs of its remuneration before its liquidation to the National Commission of the Energy. The remaining balance shall be considered as income or liquidable cost of the system for the purposes set out in Royal Decree 2017/1997.

5. Secondary regulation band.

5.1 Secondary Regulatory Band.-The secondary regulation band power allocation will result in a charging right for each unit or assigned band that is calculated according to the following formula:

DCBANu = BANu × PMBAN

where:

BANu = Secondary throttling band assigned to the u.

PMBAN = The marginal price of the secondary throttling band.

In cases where regulatory band is assigned by exceptional resolution mechanism, the price to be applied will be the result of the product of 1.15 for the marginal price of the band in the corresponding time period or, in its defect, for the maximum band price of the same time in the previous seven days.

Energy reissues to be raised or lowered to obtain the band allocated by exceptional resolution mechanism will, respectively, result in a charge or a payment obligation. The price to be applied will be the result of the product of 1.15, if it is energy to go up, or of 0.85, if it is energy to go down, for the marginal price of the daily market in the corresponding time period. The cost of this energy allocation will be the difference between the resulting amount and the result of valuing energy at the marginal price of the daily market.

5.2 Secondary regulation band variation by the operation of the secondary regulation in real time.

5.2.1 Penalization to the regulatory area for cycles in which it remains in "off".-The cost of the penalty for cycles in which zone z is in "off" will result in a payment obligation calculated according to the formula next:

OPOFFz = OFFz × PMBAN × KI

being:

OFFz =-KAz × [RNTS + RNTB] × TOFFz /TRCP

where:

PMBAN = The marginal price of the secondary throttling band.

KI = Coefficient of non-compliance published by the System Operator, prior to the authorization of the CNE. At the entry into force of this procedure, the value will be 1.5.

KAz = Coefficient of the z-regulation zone participation in the system reservation.

RNTS = Total nominal reserve to be uploaded from the system.

RNTB = Total nominal reserve to be lowered from the system.

TOFFz = Cycles in "off" of the z throttling zone, with the exception of those that are per system operator indication.

TRCP = The number of active cycles of secondary throttling in the hour.

5.2.2 Bonification to the area of regulation by residual reserve superior to the allocated one. -The residual reserve bonus greater than that allocated will result in a collection right that is calculated according to the following formula:

DCRRSz = RRSz × PMBAN × KB

being:

RRSz = (RRSPz + RRBPz) /TRCP

where:

PMBAN = The marginal price of the secondary throttling band.

KB = Bonus Coefficient that will be the same as the KI coefficient in paragraph 5.2.1.

RRSPz = Cumulative value of the positive difference between the residual reserve to be put up by the z-regulation zone and its rated power band to be raised allocated for the cycles in which the regulatory zone is active, inactive, or emergency.

RRBPz = Cumulative value of the positive difference between the residual reserve to be put down by the z-regulation zone and its rated power band to be lowered allocated for the cycles in which the regulatory zone is active, inactive, or emergency.

5.2.3 Penalization to the buffer zone per residual reserve lower than the allocated. -The cost of the penalty for lower residual reserve, which has negative value for being RRSNz and RRBNz, will give rise to a payment obligation calculated according to the following formula:

OPRRIz = RRIz × PMBAN × KI

being:

RRIz = (RRSNz + RRBNz)/TRCP

where:

PMBAN = The marginal price of the secondary throttling band.

KI = Default Coefficient that will be the same as the KI coefficient in paragraph 5.2.1.

RRSNz = The cumulative value of the negative difference between the residual reserve to be raised by the z-regulation zone and its rated power band to be allocated to the cycles in which the regulatory zone is active, inactive, or emergency.

RRBNz = Cumulative value of the negative difference between the residual reserve to be put down by the z-regulation zone and its rated power band to be lowered allocated for the cycles in which the regulatory zone is in active, inactive, or emergency.

5.3 Total fixed cost of secondary regulation band allocation. -Total fixed cost of the secondary regulatory band shall be the sum of the payment entitlements and payment obligations of paragraphs 5.1 and 5.2 except for the energy redispatch derivatives as referred to in paragraph 5.1, in which the total fixed cost of the energy redispatches shall be part of the total fixed cost.

The cost of the secondary regulatory band (CFBAN) will be borne by the acquisition units, in proportion to their high measured consumption at central bars, MBCua. (a) the acquisition units, the acquisition units corresponding to the supply of ancillary services of the production units and the acquisition units whose destination is the supply outside the Spanish electricity system

The payment obligation of each acquisition unit, au, corresponding to the payment of the band is calculated according to the following formula:

OPCFBANua = CFBAN × MBCua/ ua MBCua

6. Technical restrictions of the intraday market.

6.1 Sale offers withdrawn for solution of technical restrictions on the appeal of the intra-day market or for the subsequent generation-demand rebalancing-withdrawal of an offer of sale of energy included in the appeal the intraday market shall result in a correction of the annotation in the Spanish production market equivalent to a payment obligation for the unit or calculated according to the following formula:

OPRTMIu, s = ERVMIu, s × PMIs

where:

ERVMIu, s = Energy removed to the unit or in the constraint solution process to the corresponding intraday market session s.

PMIs = The marginal price of the corresponding intraday market session s

6.2 Acquisition offers withdrawn for the solution of technical restrictions on the appeal of the intra-day market or for subsequent generation-demand rebalancing. -withdrawal of an energy purchase offer included in the An appeal against the intraday market shall result in a correction of the taking into account in the Spanish production market equivalent to a charge for the unit or calculated according to the following formula:

DCRTMIu, s = ERCMIu, s × PMIs.

where:

ERCMIu, s = Energy removed to the unit or in the constraint solution process to the corresponding intraday market session s.

PMIs = The marginal price of the corresponding intraday market session s.

7. Technical constraints in real time.

7.1 Real-time technical constraints to upload.

7.1.1 Technical constraints in real time to rise with tertiary offer.-The allocation of energy to be put up by real time restrictions using the tertiary offer will result in a right of recovery to the unit or for each power block b calculated according to the following formula:

DCERTRTu, b = ERTRTSu, b × POTERSu, b

where:

ERTRTSu, b = Energy to be uploaded from the tertiary offering block b to be uploaded from the unit or by real-time restriction solution.

POTERSu, b = Price offered for tertiary to be uploaded for power block b.

7.1.2 Real time technical constraints to upload with submitted offer for the technical restrictions solution process of the PBF. -Energy allocation to be uploaded for security in real time using the submitted offer For the process of solution of restrictions it will result in a charge right for the unit that is calculated according to the application of the simple or complex offer.

7.1.2.1 Simple offer.-The right to collect the unit or for each block of energy b allocated is calculated according to the following formula:

DCERTROSu, b = ERTROSSu, b × POSSu, b.

where:

ERTROSSu, b = Energy to be uploaded from block b of the unit's simple offer or by real-time restriction solution.

POSSu, b = Simple offer price to upload for power block b.

7.1.2.2 Complex Offering.-The charge for the assigned energy on units that have submitted a complex offer and this is applicable is calculated according to the following formula:

DCERRTROCu = ERTROCSu × POCDIAu

where:

ERTROCSu = Power scheduled to be uploaded to the unit or by real-time restriction solution, in application of the complex offering.

POCDIAu = Applicable price for all hours of the day obtained by valuing PHF energy, deviation management, tertiary regulation, and technical constraints at the complex offer price and discounting net income positive results obtained by energy other than ERTROCSu. and by dividing the resulting amount between ERTROCSuenergy.

7.1.3 Technical constraints in real time to rise without offer.-The right to charge for the energy allocated on units that have not submitted an offer or that have exhausted the existing offer, is calculated according to the following formula:

DCERTRMERu = ERTRMERSu × 1,15 × PMD

where:

ERTRMERSu = Power scheduled to be uploaded to the unit or by real-time restriction solution with no applicable offer.

7.1.4 Failures of starts or realtime assignments to be uploaded. -Scheduled starts will be reviewed by checking if they have been effectively performed according to the measures and will check the specific type of start (cold or hot), taking into account that a cold scheduled start when revised can be converted to a hot start according to the measures received but not the other way round. For this purpose, the measures of the unit shall be taken into account in the last 5 programming periods of the day preceding the day of liquidation.

If there is a reduction in the number of starts or variation of the boot type, the collection rights calculated in paragraph 7.1.2.2 will be recalculated using the number and type of starts actually made.

In the event that in all hours with energy programmed to rise by constraints in real time, the energy measured for the unit is equal to or greater than the PHF discounting the energy management of deviations and tertiary regulation to lower the redispatches for security in real time, the collection rights calculated and revised according to the previous paragraph shall be maintained.

In the event that the measure is less than the energy programmed by restrictions in real time, the value of the unfulfilled energy shall be determined and a payment obligation calculated according to the following formula shall be recorded:

OPEINCRTRu = EINCRTRSu × (PMEDRTRSu -PMD)

where:

EINCRTRSu = Unfulfilled power of real-time constraints to be moved up from the u, zero value will be taken if the time constraints exist in real time to drop in the u.

PMEDRTRSu = Average price of all scheduled power to be uploaded for real-time technical constraint resolution to the u.

The unfulfilled power will be calculated according to the following formula:

EINCRTRSu = max [-RTRu, min (0, MBC u -(max (PHF u + TGB, 0) + RTR u))]

where:

MBC u: measured in central bars, as set out in section 13.2.

TGB: sum of deviation management and tertiary regulation power to be lowered.

RTR: Sum of power of constraints in real time.

7.2 Real-time technical constraints to download.

7.2.1 Technical constraints in real time to come down with tertiary offer.-The allocation of energy to be reduced for security in real time using the tertiary offer will result in a payment obligation to the unit or for each power block b calculated according to the following formula:

OPERTRTu, b = ERTRTBu, b × POTERBu, b

where:

ERTRTBu, b = Energy to be lowered from the b block of the tertiary offering to be lowered from the unit or by real-time restriction solution.

POTERBu, b = Bid price for tertiary to lower for power block b.

7.2.2 Technical constraints in real time to come down with offer submitted for the process of solution of restrictions. -The allocation of energy to be lowered for security in real time using the offer presented for the process of solution of restrictions, will result in a payment obligation for the unit or for each block of energy b allocated, which is calculated according to the following formula:

OPERTROSu, b = ERTROSBu, b × POSBu, b

where:

ERTROSBu, b = Energy to be lowered from block b from simple offer to drive down or by real-time restriction solution.

POSBu, b = Simple offer price to download for power block b.

7.2.3 Technical constraints in real time to go down without offer.-The obligation to pay for the energy assigned to go down on units that have not submitted offer or that have exhausted the existing offer is calculated according to the formula next:

OPERTRMERu = ERTRMERBu × 0.85 × PMD

where:

ERTRMERBu = Power scheduled to be lowered to the unit or by real-time restriction solution, with no applicable offer.

7.2.4 Real-time technical constraints to be lowered to pumping acquisition units. -In the case of pump acquisition units the allocation of energy to be lowered for security in real time will result in an obligation of additional payment for the energy reserves generated in the upper glass of the pumping unit calculated according to the following formula:

OPERTRBucb = 0.7 × (ERTRTBu, b + ERTROSBu, b + ERTRMERBu) × PMD

7.3 Overtime of the technical restrictions in real time. The cost of the technical restrictions in real time will be calculated as the difference between the sum of the receivables and the payment obligations of the paragraphs 7.1 and 7.2 and the amount of energy allocated by technical constraints in real time valued at the marginal price of the daily market.

The cost of the technical restrictions in real time (SCRTR) will be borne by the units of acquisition, in proportion to their measured consumption to central bars, MBCua. The production units, the units of purchase corresponding to the supply of auxiliary services of the production units and the units of purchase whose destination is the supply, are exempted from this allocation. out of the Spanish electrical system

The payment obligation for each acquisition unit (a) corresponding to the payment of the cost by the technical constraints in real time is calculated according to the following formula:

OPSCRTRua = SCRTR × MBCua /ua MBCua

8. International exchanges.

8.1 Support changes with price established for the same. -Support exchanges between systems performed by the System Operator through economic compensation for the energy supplied through the interconnections shall be entered for each interconnection in the System Operator account as the right to charge, if it is in the importing sense, and as an obligation to pay, if it is in the exporting sense.

The cost of the support exchanges shall be calculated as the difference between the receivables and the previous payment obligations and the amount of energy from the exchange valued at the marginal price of the daily market.

The cost of the exchange of support with established price will be borne by the units of purchase, in proportion to their measured consumption to central bars, MBCua. The production units, the units of purchase corresponding to the supply of auxiliary services of the production units and the units of purchase whose destination is the supply, are exempted from this allocation. out of the Spanish electrical system

The payment obligation for each acquisition unit, au, corresponding to the payment of the cost of the support exchanges (SCIA) is calculated according to the following formula:

OPSCIAua = SCIA × MBCua /ua MBCua

8.2 Unpriced support exchanges. -Support exchanges to be performed by the System Operator by means of the return of energy will be valued at the marginal price of the daily market by making an annotation on a Time compensation for the purposes of settlement in accordance with the provisions of the PO14.6. The annotation shall be a collection right, if the exchange is an importer and a payment obligation, if it is in the exporting sense.

The time balance of this compensation account will be allocated to the acquisition units, in proportion to their hourly consumption measured at central bars, MBCua. for the purchase of pumping, the acquisition units corresponding to the supply of ancillary services of the production units and the acquisition units whose destination is the supply outside the Spanish electricity system.

8.3 Energy interchanges between electrical systems for system security. -Energy exchanges between electrical systems for safety, programmed by technical restrictions of the PBF or by technical constraints in time actual, will result in the following annotations according to the sense of the exchange:

Importer exchange. -Right of collection in the System Operator account for the amount agreed with the neighboring system operator ..

Payment Obligation result of prior amount between the acquisition units in proportion to their hourly consumption measured to central bars, MBCua. Except for this allocation the units of the purchase of production units, the purchase units corresponding to the supply of ancillary services of the production units and the procurement units intended to be supplied outside the Spanish electricity system.

Exporter exchange. -Payment obligation in the System Operator account equal to the sum of the collected receivables to the units programmed for this energy exchange in technical constraints of the PBF or realtime, as set out in paragraphs 4.1.1. and 7.1.

9. Management of deviations.

9.1 Management of deviations to be uploaded. -Allocation of energy to be uploaded by the deviation resolution procedure results in a charge right for each unit or in the session s that is calculated according to the following formula:

DCPRDu, s = EPRDSu, s × PMPRDSs

where:

EPRDSu, s = Energy assigned to be uploaded by the bypass resolution procedure to the u drive in the s.

PMPRDSs = The marginal price of the power allocation to be uploaded by the bypass resolution procedure in the s session.

If the allocation is performed by exceptional resolution mechanism, the price to be applied will be the result of the product of 1.15 for the maximum marginal price of the allocation of deviations to be uploaded in the hour sessions or, in its defect, for the marginal price of the daily market.

9.2 Management of diversions to be downloaded.-The allocation of power to be lowered by the deviation resolution procedure results in a payment obligation for each unit in the session s that is calculated according to the following formula:

OPPRDu, s = EPRDBu, s × PMPRDBs

where:

EPRDBu, s = Energy assigned to be lowered by the bypass resolution procedure to the u drive in the s.

PMPRDBs = The marginal price of the power allocation to be lowered by the bypass resolution procedure in the s session.

If the allocation is made by exceptional resolution mechanism, the price to be applied will be the result of the product of 0.85 for the minimum marginal price of the allocation of deviations to be lowered in the hour sessions or, in its defect, for the marginal price of the daily market.

10. Tertiary regulation.

10.1 Tertiary Regulation to Rise.-The allocation of energy from tertiary energy regulation to rise gives rise to a charge right for each unit calculated according to the following formula:

DCTERu = ETERSu × PMTERS

where:

ETERSu = Tertiary energy assigned to upload to the u.

PMTERS = Marginal price of the tertiary assignment to be uploaded.

If the allocation is made by exceptional resolution mechanism, the price to be applied will be the result of the product of 1.15 for the marginal price of tertiary regulation to rise from the hour or, failing that, for the price Marginal of the daily market.

10.2 Tertiary Regulation to be lowered. -Energy allocation of tertiary energy regulation to be lowered results in a payment obligation for each unit that is calculated according to the following formula:

OPTERu = ETERBu × PMTERB

where:

eterBu = Tertiary energy assigned to download to the u.

PMTERB = The marginal rate of the tertiary allocation to be lowered.

If the allocation is made by exceptional resolution mechanism, the price to be applied will be the result of the product of 0.85 for the marginal price of tertiary regulation to fall from the hour or, failing that, for the price Marginal of the daily market.

11. Secondary regulation.

11.1 secondary regulation to be uploaded.-The contribution of secondary regulation energy to be raised for each z-regulation zone gives rise to a charging right which is calculated according to the following formula:

DCSECz = ESECSz × PMSECS × CATS

where:

CATS = 1 if the tertiary ladder has not been exhausted to rise, otherwise, CATS will be equal to 1.15.

ESECSz = Secondary throttling energy to be uploaded by the z throttling zone.

PMSECS = Marginal price of secondary throttling energy contributed to upload.

11.2 secondary regulation to be lowered. -Secondary regulation power allocation to be lowered results in a payment obligation for each z-regulation zone calculated according to the following formula:

OPSECz = ESECBz × PMSECB × CATB

where:

CATB = 1 if the tertiary ladder has not been exhausted, otherwise CATB will be equal to 0.85.

ESECBz = Secondary throttling energy contributed to download by the z throttling zone.

PMSECB = marginal price of secondary throttling energy contributed to download.

12. Reduction of the power consumption program by power reduction orders. -The reduction of the scheduled power consumption in the market for each unit of purchase due to power reduction orders will be settled at the price of the power reduction. According to the provisions of Order ITC/2370/2007 of 26 July 2007, the market for the management of the demand for interruptibility is regulated for consumers who acquire their energy in the production market.

In each hour with reduced power consumption of an acquisition unit, ua, due to power reduction orders, a charging right shall be entered for the au unit calculated according to the following formula:

DCSINTua = ERSINTua x PMD

where:

ERSINTua = High power to central bars of the time consumption reduction due to power reduction orders to consumers integrated into the ua unit.

PMD = Daily market marginal price.

13. Detours between measure and settlement program.-The deviation will be calculated based on the measure in central bars (MBC) and the Schedule of Liquidation Schedule (PHL).

13.1 Schedule of Liquidation Schedule (PHL) of the unit or will be calculated as the sum of:

End Time Program (PHF) Energy,

Energies assigned in the Operating Schedule Program, excluding the power of the communicated deviations.

Reduction of consumption due to ERSINT power reduction ordersua

13.2 Measure in Central Bars. -Unit Central bar measure or will be determined according to the following criteria:

(a) The measure in the central bars of the production programming units, the pumping consumption programming units and the auxiliary service consumption programming units, shall be the sum of the measures of the border points allocated to the production facilities that make up each programming unit.

In the case of the absence of measures of the production programming units, the value of the measure is considered to be zero. In the case of the absence of measures of the pumping consumption programming units, the value of the programme shall be considered as the value of the measure.

In cases where the measure of a border point collects the production of several production facilities, this value shall be apportioned in proportion to the individual measures or, in the case of the absence of an individual measure for the installation, proportionally to the value of the installed power.

(b) The measure in central bars of import programming units shall be the energy allocated to the unit in the exchange programme at the international border agreed by both system operators.

(c) The measure in central bars of export programming units shall be the energy allocated to the unit in the exchange programme at the international border agreed by both system operators, plus losses transport in the case of exports by borders with countries with which no reciprocal agreement has been signed, according to the following formula:

MBCuexp = PFIuexp × (1 + CPERfrint)

where:

MBCuexp = Central bar metric of the uexp export programming unit.

PFIuexp = Energy assigned to the uexp export unit in the international border exchange program agreed by both system operators.

CPERfrint = Coefficient loss of the general high voltage access rate for the international frint border. The applicable value, in the case where the losses are applied, shall be that corresponding to the voltage level 'greater than 145 kV' except for the interconnection with Andorra which shall be, if applicable, the one corresponding to the voltage level 'greater than 72,5 and not more than 145 kV'. At the borders with the countries with which the reciprocal agreement has been signed, the value shall be zero.

(d) The measure in central bars of the marketing units and direct consumer units shall be calculated using the following formula:

MBCuc =nt tata [MPFCuc, nt, ta × (1 + CPERnt, ta)]

where:

MPFCuc, nt, ta Sum of the energy measures consumed at the consumer border points to the direct consumer or marketer programming unit at voltage level nt and access rate. This value will be negative.

CPERnt, ta Loss Coefficient for access contracts on supply points to consumers with voltage level nt and access rate ta and for the corresponding tariff period for the time in the access rate The This value will be positive.

These coefficients will be those set out in the regulations establishing the electricity tariff of each year to transfer the energy supplied to the consumers in their meters to energy supplied in bars (a) the effects of the liquidations provided for in Royal Decree 2019/1997 of 26 December 1997.

The tariff periods shall be those laid down in Article 8 of Royal Decree 1164/2001. For two-and three-term fares, the 23-hour day will be the first day of summer and the 25-hour day will be the first of winter. For the six-term fee, national holidays for each year will be published by the System Operator as set out in P.O. 14.1.

In the event that complete measures are not available, and therefore no measures are available for the marketing programming units and direct consumers the measure in the central bars of these units will be the resulting value of the following formula:

MBCua = PHLua + SALDOENEua

where:

PHLua = The acquisition unit's Schedule of Liquidation Schedule for ua, excluding the program fee for the central bar consumption of type 1 clients of the ua unit to which it has been applied the potestative settlement established in P.O. 14.1.

SALDOENEua = Allocation to the acquisition programming unit for the au of the settled power balance of the programs and the available measures on central bars (SALDOENE). The allocation shall be carried out in proportion to the Schedule of Liquidation Schedule of each unit according to the following formula:

SALDOENEua = SALDOENE × PHLua/ua PHLua

e) The measure of the generic programming units is zero.

13.3 Price of deviations. -For the purposes of paragraph 12.5, the net balance SNSB of the energy to be raised and to be assigned by the procedure for the resolution of deviations, by tertiary regulation and to be reduced, shall be calculated. by secondary regulation.

SNSB=u,(EPRDSu, s+ EPRDBu, s) +u,(ETERSu+ ETERSu) +z (ESECSz+ ESECBz)

13.3.1 Price of detours to rise. -They are defined as deviations to increase the deviations in the sense of greater generation and the deviations in the sense of less consumption.

If SNSB is negative, the time price of the deviations to be uploaded, for the purposes of paragraph 12.5, shall be calculated using the following formula:

PDESVS = minimum (PMD, PMPRTSB)

where:

PMPRTSB = weighted average price of the energy to be reduced as assigned by the deviation resolution procedure, by tertiary regulation and by secondary regulation according to the amounts recorded in accordance with the provisions of the paragraphs 9.2, 10.2, and 11.2 respectively, rounded to two decimal places.

If there is no value for PMPRTSB or, if SNSB is non-negative, the price of the deviations to be uploaded will be the marginal price of the daily market.

13.3.2 Price of deviations to be lowered. -They are defined as deviations to lower the deviations in the sense of the lowest generation and the deviations in the sense of greater consumption.

If SNSB is positive, the time price of the deviations to be lowered, for the purposes of paragraph 12.5, will be calculated using the following formula:

PDESVB = maximum (PMD, PMPRTSS)

where:

PMPRTSS = weighted average price of the energies to be assigned by the deviation resolution procedure, by tertiary regulation and by secondary regulation according to the amounts scored according to the provisions of the paragraphs 9.1, 10.1 and 11.1 respectively, rounded to two decimal places.

If there is no value for PMPRTSS or if SNSB is non-positive, the price of the deviations to be lowered will be the marginal price of the daily market.

13.4 Deviation calculation.

13.4.1 Desaw from the Regulatory Zones. -The detour of each z-regulation zone will be calculated using the following formula:

DESVz =u (MBCu -PHLu) x PUZu, z -(ESECSz + ESECBz)

where:

MBCu = The central bar metric of the programming unit or integrated in the z-regulation zone.

PHLu = Schedule unit of the programming unit or integrated in the z-regulation zone.

PUZu, z = The integration percentage of the programming unit or the z-throttling zone.

ESSECz = Secondary throttling energy to be uploaded by the z-regulation zone.

EBSECz = Secondary throttling energy to be brought down by the z-regulation zone.

13.4.2 Unintegrated programming units in regulation zone. -The detour of each programming unit, or non-integrated in regulatory area, of each unit of demand acquisition, of each unit of import or export and generic units will be calculated using the following formula:

DESVu = (MBCu -PHLu)

where:

MBCu = A measure raised to central bars of each production or acquisition unit or, as set out in paragraph 13.2.

PHLu = The time schedule cleared for each of each production or acquisition unit or, as set out in paragraph 13.1.

13.5 Collection rights and payment obligations for deviations. -For the purposes of determining the payment entitlements and payment obligations for deviations, the deviations will be calculated as follows:

The deviation of each regulatory area shall be the deviation calculated in paragraph 13.4.1.

The diversion of each Liquidation Subject to the special regime production activity shall be the sum of the deviations of its special regime programming units not belonging to the regulatory area. The deviation of each unit shall be that calculated in paragraph 13.4.2.

The diversion of each Liquidation Subject by the production activity under ordinary regime shall be the sum of the deviations of its non-regulatory units of ordinary regime programming units. The deviation of each unit shall be that calculated in paragraph 13.4.2.

The diversion of each Liquidation Subject to the marketing activity for domestic and acquisition customers for direct consumers will be the sum of the diversion of its programming units and the deviations of those (a) the acquisition programming units for domestic customers of other traders with whom it has made bilateral contracts and is the trading subject responsible for the system operator of its management, by virtue of the provisions of Article 20.6 of Royal Decree 2019/1997, as amended by the Royal Decree Decree 1454/2005, and in the P.O.14.1. The deviation of each unit shall be that calculated in paragraph 13.4.2.

The diversion of each of the international borders of each authorized subject for international export exchanges will be the sum of the deviations of their export programming units at each border. The deviation of each unit shall be that calculated in paragraph 13.4.2.

The diversion of each of the international borders of each authorized subject for international import exchanges will be the sum of the deviations of their import programming units at each border. The deviation of each unit shall be that calculated in paragraph 13.4.2.

The deviation of each subject by the generic programming units that are instrumentally enabled in the current regulations will be the sum of the deviations of these units. The deviation of each unit shall be that calculated in paragraph 13.4.2, considering a measure value equal to zero.

13.5.1 Positive. -If the deviation d calculated as set out in the initial paragraphs of paragraph 12.5. is positive, the price to be applied to the detour d will be the price of the detour to be uploaded, PDESVS, calculated as determined in paragraph 13.3. The amount shall be positive and shall be calculated using the following formula:

ECODESVd = DESVd × PDESVS

The amount will be supported by the programming units or regulatory zones that produce the d-deviation according to the following criteria:

a) The unit u or zone z whose contribution to the deviation d has been negative (DESVuz, d< 0) shall have a payment obligation which shall be calculated with the following formula:

OPPDESVuz, d = DESVuz, d × PMD

b) The z unit or zone that has contributed positively (DESVuz, p > 0) to the deviation d will have a charging right that will be calculated with the following formula:

DCDESVuz, d = DESVuz, d × PMD + DESVuz, d × DESVd ×PDESVS-PMD)/u DESVPuz, d

where:

u DESVPuz, d = sum of positive detours DESVPuz, d = DESVuz, d> 0

As a result of annotations on a. and b. The above is equality:

ECODESVd =uzDCDESVuz, d + uz OPPDESVuz, d

13.5.2 Negative. -If the deviation d calculated as set out in the initial paragraphs of paragraph 13.5 is negative, the price to be applied to the detour d will be the price of the detour to be lowered, PDESVB, calculated according to the paragraph 13.3. The amount shall be negative and shall be calculated using the following formula:

ECODESVd = DESVd × PDESVB

The amount will be supported by the programming units or regulatory zones that produce the d-deviation according to the following criteria:

a) The unit u or zone z whose contribution to the deviation d has been positive (DESVuz, d> 0) shall have a charging right which shall be calculated with the following formula:

DCDESVuz, d = DESVuz, d × PMD

b) The unit u or zone z that has contributed negatively (DESVuz, d< 0) to the deviation d will have a payment obligation that will be calculated with the following formula:

OPPDESVuz, d = DESVuz, d × PMD + DESVuz, d × DESVd ×PDESVSB-PMD)/u DESVNuz, d

where:

u DESVNuz, d = sum of the negative detours DESVNuz, d = DESVuz, d< 0

As a result of annotations on a. and b. The above is equality:

ECODESVd =uzDCDESVuz, d + uz OPPDESVuz, d

13.5.3 Zero-Off. -If the deviation d calculated as set out in the initial paragraphs of paragraph 13.5 is zero, the economic amount will be zero. The payment entitlements and the payment obligations of the programming units producing the zero deviation shall be calculated according to the following criteria:

a) The unit or positive detour (DESVu, d > 0) will have a charging right that will be calculated with the following formula:

DCDESVu, d = DESVu, d × PMD

b) The unit or negative deviation (DESVu, d < 0) will have a payment obligation that will be calculated with the following formula:

OPPDESVu, d = DESVu, d × PMD

13.5.4 Cancellation of the cost of diversion of exempt facilities. -Programming units that exclusively integrate special regime facilities completely exempt from payment of the cost of the deviations will have in each period Programming schedule a right to charge in respect of the cancellation of the cost of the diversion to be calculated according to the following formula:

DCDSVEXu = Abs (DESVEXu) x Abs (PMD-PREDESVu)

where:

DESVEXu = Unexempted from the programming unit or calculated in accordance with paragraph 12.4.2 which will be positive or negative as appropriate to higher or lower production than expected. The exemption is limited to deviations from the installed power, in the case of a programme exceeding that power.

PREDESVu = Price of the payment entitlement or payment obligation of the programming unit or per deviation as provided for in paragraphs 13.5.1, 13.5.2 and 13.5.3, result of the ratio between the annotated amount and the energy of the detour.

PMD = Daily market time price.

The sum of the receivables for cancellation of the cost of the deviations shall constitute the deficit of deviations exempt from the payment of the cost of deviations that will be settled from the balance of the surplus or deficit of valuation of the deviations of the paragraph 12.10 in which the sum of these receivables shall be included.

13.6 International Devios between Systems. -International deviations between systems are calculated as a difference between the measure at the border points with other electrical systems and the program agreed between the operators of systems. The marginal price of the day-to-day market shall be valued at an annotation in a time-clearing account for settlement in accordance with the provisions of the P.O.14.6.

In each hour, international deviations will be added for each international interconnection.

DIR =frint DIRfrint

where:

DIRfrint = International Desvio at border frint,

If the sum of all international deviations from regulation is positive, a claim that will be calculated using the following formula shall be entered in the clearing account:

DCDIR = DIR × PMD

If the sum of all international regulatory deviations is negative, a payment obligation shall be entered in the clearing account that is calculated using the following formula:

OPDIR = DIR × PMD

The time balance of this compensation account will be allocated to the acquisition units, in proportion to their hourly consumption measured at central bars, MBCua. for the purchase of pumping, the acquisition units corresponding to the supply of ancillary services of the production units and the acquisition units whose destination is the supply outside the Spanish electricity system.

13.7 Coordinated Balance Sheet Actions with Other Systems. -Energy from coordinated balancing actions with other systems shall be valued from the Spanish system at the price of deviations as set out in paragraph 12.3. to the sense corresponding to the balancing action. An hourly annotation shall be performed for each interconnection in the System Operator account for use in accordance with the provisions of the P.O.4.1.

If the balance sheet action is in the importing sense (ABI), a collection right shall be recorded which shall be calculated using the following formula:

DCAB = ABI × PDESVS

If the balance sheet action is in the exporting sense (EBA) a payment obligation shall be entered in the following formula:

OPAB = EBA × PDESVB

13.8 Energy Closure. -In the closing of measures, the power closure in each hour, the REDRE, is calculated as the difference between the losses of transport and distribution and the calculated standard losses in accordance with the provisions of the second provision of Royal Decree 485/2009 of 3 April 2009, which regulates the implementation of the supply of last resort in the electricity sector.

RE = PRTD-tant [MPFCuc, nt, ta × CPERnt, ta]

where:

PRTD = PT +d PRDd

PT = Lost transport network measures. This value will be negative.

PRDd = Measures of the distributor distribution network d. This value will be negative.

The system power shutdown calculated according to the formula above will be valued at the daily market price.

The payment entitlements for positive closures and the payment obligations for negative closures shall be settled in the system operator's account. The resulting balance shall be considered as income or liquidable cost of the system for the purposes of Royal Decree 2017/1997 and as such shall be included in the liquidations of the regulated activities as provided for in the second provision of the Royal Decree 485/2009,.

13.9 Allocation of surplus or deficit in the valuation of deviations. -As a consequence of the method of valuation of the deviations, the balance resulting from the set of payment entitlements and payment obligations in one hour (SALDOLIQ) will be a surplus, or, where appropriate, a deficit.

The surplus (SALDOLIQ < 0) will be distributed to the acquisition units, in proportion to their measured consumption to central bars, MBCua as a minorage of the technical and band constraints costs. The production units, the units of purchase corresponding to the supply of auxiliary services of the production units and the units of purchase whose destination is the supply, are exempted from this allocation. out of the Spanish electrical system

In case of surplus these units will have a right of collection in the time of adjustment that will be calculated with the following formula:

DCAJDVu =-SALDOLIQ x MBCua /u MBCau

In the event that a deficit occurs in the hour (SALDOLIQ > 0) the previous units will have a payment obligation in the time of adjustment that will be calculated with the following formula:

OPOPJDVu =-SALDOLIQ x MBCua /u MBCau

14. Programming failure of the generic programming units.

14.1 Obligation to pay for non-compliance with the zero balance obligation in PBF. -Following the mandatory report of the National Energy Commission, the non-zero balance of the energies of all the programming units generic of each market subject in the PBF will result in the following payment obligation:

OPUPGPBF= -abs (ugENPBFug) × PMD x 1.3

where:

ENPBFug = Energy in PBF of the generic programming unit ug.

This payment obligation may be moderated in accordance with the circumstances of the case, taking into account the damage to the system and the diligence of the defaulting agent.

14.2 Obligation to pay for non-compliance with the zero balance obligation in the PHF. -Following the mandatory report of the National Energy Commission, the non-zero balance of the energies of all the programming units generic of each market subject in the PHF will result in the following payment obligation in each hour h:

OPUPPGPH= -abs (ug ENPHFug) × PMD x 0.15 x NS

where:

ENPHFug = Energy in the last PHF of the generic programming unit time ug.

NS = Number of valid intraday market sessions for hour h.

This payment obligation may be moderated in accordance with the circumstances of the case, taking into account the damage to the system and the diligence of the defaulting agent.

14.3 Surplus by payment obligations due to programming failures.-The surplus generated by the payment obligations of paragraphs 14.1 and 14.2 shall be divided according to the method described in paragraph 13.9 of the surplus or deficit in the valuation of deviations.

15 Communication for the purpose of the liquidation of the equivalent premium. -Special scheme production facilities which have chosen the option of sale corresponding to Article 24 (1) (a) of Royal Decree 661/2007, The equivalent premium shall be settled with the National Energy Commission of 25 May.

As set out in Circular 4/2009 of 9 July, of the National Energy Commission, which regulates the request for information and the procedures for implementing the system of settlement of equivalent premiums, premiums, the incentives and additions to the electrical energy production facilities under special arrangements, the system operator shall communicate monthly to the National Energy Commission, the aggregate amount of the base for the settlement of the difference with the regulated tariff (Baldita) corresponding to the set of the installations of each representative and each holder who participates without a representative and who has chosen option (a) of Article 24.1 Royal Decree 661/2007.

The amount of the basis for the settlement of the difference with the regulated tariff, BALDITA, of each representative or rt holder in each month m shall be the sum of the amounts of the settlements referred to in Article 30.1 and the amount of the impact of the cost of the diversion referred to in Articles 30.1 and 34 of Royal Decree 661/2007. The value of this sum is calculated according to the following formula:

BALDITArt, m = MEDPMDrt, m + EMIPIDrt, m

being:

MEDPMDrt, m = Value of the time measures, MEAMID, of the net energy effectively produced by the representative or rt holder's facilities in the month m valued at the daily market price, PMD, in each hour h:

MEDPMDrt, m = Σi, h MEP, rt, h × PMDh

EMIPIDrt, m = The value of the monthly gain or loss by the married energies at each session of the intraday market of hour h, EMI, by the facilities i of the representative or rt holder in the month m, integrated into the (a) the following information shall be obtained from the following:

a) the following information: (a) the price of the intra-day market session, the price of the intra-day market session;

EMIPIDrt, m = Σi, s, h EMIi, rt, s, h× (PMIs, h -PMDh) = Σup, s, h EMIup, rt, s, h × (PMIs, h -PMDh)